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API Manual of Petroleum Measurement StandardsChapter 12 - Calculation of Petroleum QuantitiesSection 1 - Calculation of Static Petroleum QuantitiesPart 1 - Upright Cylindrical Tanks and Marine VesselsThird Edition, xx/xxxxEI HM1 Part 1Foreword
This two-part publication presents standard calculation procedures for static petroleum liquids. The
two parts consist of the following:
Part 1 - “Upright Cylindrical Tanks and Marine Vessels” - 10/2001
Part 2 - “Calculation Procedure for Tank Cars” – 5/2003
This standard has been developed through the cooperative efforts of many individuals from industry
under the sponsorship of the American Petroleum Institute and the Energy Institute.
Suggested revisions to this publication are invited and should be submitted to the Measurement Coordinator, Exploration and Production Department, American Petroleum Institute, 1220 L Street, N.W., Washington, D.C. 20005.
Contents
Section 1 - Calculation of Static Petroleum Quantities
Part 1 - Upright Cylindrical Tanks and Marine Vessels
0 Introduction
1 Scope
2 References
3 Definitions
3.1 General
3.2 Abbreviations
4 Interrelationship between Chapter 12 and Chapter 11.1
5 Hierarchy of Accuracies
6 Rounding and Discrimination
6.1 Data Level
6.2 Rounding of Numbers
6.3 Discrimination
7 Observed Data (Input, Direct, or Primary)
8 Calculated Data (Indirect or Secondary)
9 Calculation of Gross Observed Volume (GOV)
9.1 Shore Tanks
9.1.1 Total Observed Volume (TOV)
9.1.2 Adjustment for the Presence of Free Water (FW) and Tank Bottom Sediments
9.1.3 Correction for the Effect of Temperature on the Steel Shell of the Tank (CTSh)
9.1.4 Floating Roof Adjustments and Corrections (FRA) & (FRC)
9.2 Marine Vessel’s Tanks
9.2.1 Total Observed Volume (TOV)
9.2.2 Trim Correction
9.2.3 List Correction
9.2.4 Combining Trim and List Corrections
9.2.5 Free Water Volume (FW)
10 Calculation of Gross Standard Volume (GSV) and Total Calculated Volume (TCV) - Shore Tanks and
Marine Vessel’s Tanks
10.1 Gross Standard Volume (GSV)
10.2 Correction for the Effect of Temperature on a Liquid (CTPL) or Volume Correction Factor (VCF)
10.3 Total Calculated Volume (TCV)
11 Calculation of Net Standard Volume (NSV)
11.1 Calculation of the Correction for Sediment and Water (CSW)
11.2 Calculation of the Volume of Sediment and Water (S&W)
12 Calculation of Mass (Weight in Vacuum) and Weight (Weight in Air)
12.1 Introduction
12.2 Calculation Methods
12.2.1 Volume at Standard Temperature to Mass/Weight
12.2.1 Volume at Observed Temperature to Mass/Weight
12.2.3 Calculation of Gross Standard Weight and Net Standard Weight
12.2.4 Calculation of Gross Standard Mass and Net Standard Mass
12.3 Converting Between Mass and Weight
13 Direct Mass Measurement
14 Calculation Sequence
14.1 General
14.2 Volume at Standard Temperature to Mass/Weight Calculation Procedure
14.3 Volume at Observed Temperature to Mass/Weight Calculation Procedure
15 Calculation of Transferred Volumes for Custody Transfer
15.1 General
15.2 Small Lease Tanks
15.2.1 Transferred Volume Calculation Procedure for Lease Tanks
15.3 Volumetric Shrinkage
16 Miscellaneous
16.1 Precautions When Using an Automatic Sampler
16.2 Interrelation of Units
Annex A - Examples of Shore Tank and Marine Vessel Tank Calculations
A1 Custody Transfer Flow Chart – Shore Tank(s) with Automatic Sampler
A2 Custody Transfer Flow Chart - Shore Tank(s) with Individual Tank Samples
A3 Shore Tank Calculation Using Volume At Standard Temperature To Mass/Weight Calculation
Procedure
A4 Marine Vessel Tank Calculation Using Volume at Standard Temperature To Mass/Weight
Calculation Procedure
A5 Shore Tank Calculation of Volume at 15ºC and Weight of p-Xylene using ASTM D1555M
A6 Shore Tank Calculation of Volume at 15ºC, Mass and Weight of MTBE using API MPMS Chapter
11.1/Adjunct to ASTM D1250/Adjunct to IP 200, Table 54C
A7 Shore Tank Calculation of the Weight of Benzene Using Density Correction Coefficients
Annex B - Example of Shell Temperature Correction Factors for Expansion and contraction of
Upright Cylindrical Steel Tanks Due to Temperature
B1 Shell Temperature Correction Factors for Expansion and Contraction of Upright Cylindrical Steel
Tanks Due to Temperature
B2 Application of Shell Temperature Correction
Table B-1 - Correction Factors for Effect of Temperature on the Tank Shell – Reference Temp 60ºF Table B-2 - Correction Factors for Effect of Temperature on the Tank Shell – Reference Temp 15ºC Table B-3 - Linear Thermal Expansion Coefficients of SteelAnnex C - Examples of Floating Roof Adjustment Calculations: Methods 1 and 2
C1 Example when roof calculation is calculated into the tank capacity table
C2 Example when roof adjustment is not calculated in the tank capacity table
Figures
1 -Method to Calculate Vessel’s List Using Amidships Draft Readings
Tables
1 - Significant Digits
2 - Observed Data
3 - Calculated Data
4 - Generalized Crude Oils API Correction to 60ºF
5 - Mass to Weight Density Corrections
6 - Excerpt from API MPMS Chapter 11.1/Adjunct to ASTM D1250/Adjunct to IP 200, Table 5A.
B-1 - Correction Factors for Effect of Temperature on the Tank Shell – Reference Temp 60ºF
B-2 - Correction Factors for Effect of Temperature on the Tank Shell – Reference Temp 15ºC B-3 - Linear Thermal Expansion Coefficients of Steel
API Chapter 12 - Calculation of Petroleum Quantities
Section 1 - Calculation of Static Petroleum Quantities
Part 1 - Upright Cylindrical Tanks and Marine VesselsEI HM1 Part 10 IntroductionThese procedures are intended to encourage a uniform approach to volumetric and mass calculation
of crude oil, petroleum products, and petrochemicals when contained in tanks. This publication will also address calculation sequences, rounding, and significant digits, with the aim that different operators can produce identical results from the same observed data.
1 ScopeThis standard is intended to guide the user through the steps necessary to calculate static liquid
quantities, at atmospheric conditions, in upright, cylindrical tanks and marine tank vessels. The standard defines terms employed in the calculation of static petroleum quantities.
The standard also specifies equations that allow the values of some correction factors to be computed. Fundamental to this process is the understanding that in order for different parties to be able to reconcile volumes, they must start with the same basic information (tank capacity table, levels, temperatures, and
so forth) regardless of whether the information is gathered automatically or manually.
This standard does not address the calculation of clingage, non-liquid material, small quantities (such as onboard quantities, quantities remaining on board, and Wedge Formula, where material is not touching all bulkheads on marine vessels), and vapor space calculations.
2 ReferencesThe following documents are referenced throughout this standard:
API
Manual of Petroleum Measurement Standards (MPMS)
Chapter 1, “Vocabulary” Chapter 2, “Tank Calibration” Chapter 3, “Tank Gauging”
Chapter 7, “Temperature Determination” Chapter 8, “Sampling”
Chapter 9, “Density Determination” Chapter 10, “Sediment and Water” Chapter 11, “Physical Properties Data”
Chapter 15, “Guidelines for the Use of International System of Units (SI) in the Petroleum and Allied
Industries”
Chapter 16, “Measurement of Hydrocarbon Fluids by Weight or Mass” Chapter 17, “Marine Measurement”
Chapter 18, “Custody Transfer”
ASTM1
Adjunct to D1250 Temperature and Pressure Volume Correction Factors for Generalized Crude
Oils, Refined Products, and Lubricating Oils
D1555 Test Method for Calculation of Volume and Weight of Industrial Aromatic
Hydrocarbons and Cyclohexane
D4311 Practice for Determining Asphalt Corrections to a Base Temperature
1 American Society for Testing and Materials, 100 Bar Harbor Drive, West Conshohocken, PA 19428, USA.
IP2
Adjunct to IP 200 Temperature and Pressure Volume Correction Factors for Generalized Crude
Oils, Refined Products, and Lubricating Oils
3 Definitions3.1 GENERAL
The definition of those terms relative to this document can be found in other API or associated documents, as follows:
General Terms - API MPMS Chapter 1
Marine Terms - API MPMS Chapter 17.1 (17.1.3)
Units of Measure and Interrelation – API MPMS Chapter 11.5
International System (SI) Units - API MPMS Chapter 15
3.2 ABBREVIATIONS AND DEFINITIONS
The designation of corrections and correction factors by abbreviations rather than words is recommended to abbreviate the expression, facilitate algebraic manipulation, and reduce confusion. While a combination of upper case, lower case, subscripted, and superscripted notation is used, upper case notation may be used as appropriate. Additional letters may be added to symbolic notations for clarity and specificity.
3.2.1
coefficient of thermal expansion per degree
Cs
The amount by which the density of a material changes, per degree, due to a change in temperature.
3.2.2
correction for sediment and water.
CSW
Corrects a volume, usually at standard temperature, for the effects of suspended sediment and water.
3.2.3
correction for the temperature and pressure of the liquid
CTPL
Corrects a volume at an observed temperature & pressure to an equivalent volume at base temperature and pressure and is equal to CTL x CPL. For the purpose of this standard, base pressure is equivalent to atmospheric pressure and the CPL factor is considered to be 1.00000; therefore, under atmospheric conditions, the CTPL and CTL will be the same value. (CTPL and CTL are referred to as VCF in some
API MPMS standards)
3.2.3.1
correction for the temperature of the liquid
CTL
Compensates for the effect of temperature on a liquid.
3.2.3.2
correction for the pressure of the liquid
CPL
Compensates for the effect of pressure on a liquid.
2 Energy Institute, formerly the Institute of Petroleum, 61 New Cavendish Street, London W1G 7AR, UK.
3.2.4
correction for temperature of the shell
CTSh
The correction factor for the effect of the temperature, both ambient and liquid, on the shell of the tank.
3.2.5
density
Mass per unit volume; i.e. the mass of a substance divided by its volume. When reporting density, the unit used together with temperature shall be explicitly stated; for example, kilograms per cubic meter at 15ºC
or lbs per gallon at 60ºF.
3.2.6.1
floating roof adjustment
FRA
A secondary correction or adjustment for any difference between the reference density and the observed density at tank temperature, when a correction for the roof has been calculated into the tank capacity table using a reference density.
3.2.6.2
floating roof correction
FRC
The correction made to offset the effect of the displacement of the floating roof, when no correction has been built into the tank capacity table.
3.2.7
free water
FW
The water present in a container that is not suspended in the liquid hydrocarbon. A free water quantity deduction may include bottom sediments.
3.2.8
gross observed volume
###
###
###
###
###
###
###
###
###
###
###
GOV
The total volume of all petroleum liquids and sediment and water, excluding free water, at observed temperature and pressure.
3.2.9
gross standard volume
GSV
The total volume of all petroleum liquids and sediment and water, excluding free water, corrected by the appropriate volume correction factor (CTPL) for the observed temperature and API gravity, relative density, or density to a standard temperature such as 60ºF or 15ºC.
gross standard mass
GSM
The mass of the GSV quantity.
gross standard weight
GSW
The weight of the GSV quantity.
mass
The technical description of mass exists in API MPMS Chapter 11.5; however, within this document it
refers to “weight in vacuum”.
net standard volume
NSV
The total volume of all petroleum liquids, excluding sediment and water and free water, corrected by the appropriate volume correction factor (CTPL) for the observed temperature and API gravity, relative density, or density to a standard temperature such as 60ºF or 15ºC.
net standard mass
NSM
The mass of the NSV quantity.
net standard weight
NSW
The weight of the NSV quantity.
tank shell reference temperature
TShREF
The tank shell temperature used to calculate volumes in the preparation of a tank capacity table;
frequently 60°F, or 15°C, although other temperatures are used.
total calculated volume
TCV
The total volume of all petroleum liquids and sediment and water corrected by the appropriate volume correction factor (CTPL) for the observed temperature and API gravity, relative density, or density to a standard temperature such as 60ºF or 15ºC and all free water measured at observed temperature (gross standard volume plus free water).
total observed volume
TOV
Total measurement volume of all petroleum liquids, sediment and water, free water, and bottom sediments at observed temperature. For the purposes of this standard, TOV is the volume taken from the tank capacity table prior to any corrections, such as those for floating roof and the temperature of the tank shell.
temperature of the tank shell
TSh
Observed temperature of the metal (usually steel) shell of the tank.
###
volume correction factor
VCF
This is the same as CTL and under atmospheric conditions is also the same as CTPL, making these three symbols interchangeable; however, only CTPL and CTL are used in equations in this standard.
weight
The technical description of weight exists in API MPMS Chapter 11.5; however, within this document it
refers to “weight in air”.
4 Interrelationship between Chapter 12 and Chapter 11.1Currently, the Manual of Petroleum Measurement Standards is organized into Chapters covering general measurement areas and several of these Standards are interrelated, in particular Chapters 11 and 12. If there is uncertainty amongst users as to which takes precedence the following criteria should be applied.
API MPMS Ch. 11.1 is the primary standard for the determination of the temperature (CTL), pressure (CPL), and combined temperature and pressure (CTPL) correction factors for crude oil, refined products, and lubricating oils, either by presentation of specific implementation procedures or by reference to other publications.
API MPMS Ch. 12 is the primary standard for the calculation of volume quantities. It determines the
discrimination levels (rounding) required for each input variable and correction factor in a specific volume calculation procedure, and the sequence and manner in which to apply the appropriate parameters (RHO b, APIb, RDb, CTL, Fp, CPL, and CTPL).NOTE: The terms RHOb, APIb, RDb, and Fp, are not used in this document.
RHO refers to density, API refers to API Gravity and RD refers to relative density. Subscript “b” refers to
“base” conditions. The “standard” or “base” condition is a defined combination of temperature and pressure at which liquid volumes are expressed for purposes of custody transfer, stock accounting, etc. The terms
standard and base are used interchangeably. Accepted standard temperatures are 60°F, 15°C and 20°C.
Accepted standard pressures are zero gauge pressure (for non-volatile liquids at the standard temperature)
or the liquid’s vapor pressure at the standard temperature (for volatile liquids).
Fp is called the "compressibility coefficient" or "scaled compressibility factor (units of 1/psi)". For additional information on these terms, refer to API MPMS Chapter 11.1.
5 Hierarchy of AccuraciesA hierarchy of accuracies applies in petroleum measurement. At the top are the standards calibrated
by a National Metrology Institute (NMI) such as the National Institute of Standards and Technology (NIST) in the United States. From this level downwards, any uncertainty in a higher level must be reflected in all lower levels as a bias or systematic error. Whether such bias will be positive or negative is unknown as uncertainty carries either possibility.
To expect equal or less uncertainty in a lower level of the hierarchy than exists in a higher level is unrealistic. The only way to decrease the random component of uncertainty in a given measurement system is to increase the number of determinations and then find their mean value. The number of digits in intermediate calculations of a value can be larger in the upper levels of the hierarchy than in the lower levels, but the temptation to move towards imaginary significance (more decimal places) must be tempered or resisted by a wholesome respect for realism.
6 Rounding and Discrimination6.1 DATA LEVEL
In many cases the number of decimal places that are to be used is influenced by the source of the
data itself. For example, if a vessel’s capacity tables are calibrated to the nearest whole barrel, than all subsequent barrel values should be recorded accordingly. However, in those cases where there are no other limiting factors, the operator should be guided as follows by Table 1.
Table 1 - Significant DigitsUnits No. of
Decimals UnitsNo. ofDecimals
LitersGallons
…, xxx.0…, xxx.xx
API Gravity @ 60ºF CTPL xxx.x x.xxxxxa
BarrelsCubic meters
…, xxx.xx…, xxx.xxx
Density lbs/galDensity kg/m3
xx.xxxxxxx.x
Pounds …, xxx.0 Density kg/litre x.xxxxKilograms …, xxx.0 Density correction coefficient x.xxxxxShort tons …, xxx.xxx Relative density x.xxxxMetric tons …, xxx.xxx S & W % xx.xxxLong tons …, xxx.xxx CSW x.xxxxx
Temperature ºFTemperature ºC
xxx.x xxx.xa
TSh ºC / ºF (See Section 9.1.3) xxx.0CTSh x.xxxxx
Note a Not applicable if the implementation guidelines (“Grandfather Clause”) from API MPMS Chapter
11.1-2004 have been invoked. For those invoking the “Grandfather Clause”, the following note, from API MPMS Chapter 11.1-1980, which was applicable to the CTL, is reproduced here for ease of reference. “The standard for determining CTL factors is the computer subroutine implementation procedures of API MPMS Chapter 11.1, Volume X. When fully implemented, this generates a CTL factor of five significant digits. That is, five decimal digits at temperatures above standard temperature (60ºF and 15ºC) and four decimal digits at temperatures below standard temperature. Use of the printed table limits the user to
four decimal digits above and below standard temperature in addition to limiting table entry discrimination to 0.5ºF, 0.25ºC, 0.5 API, and 2.0 kg/m3. In the event of dispute, the computer-generated CTL should take preference.”
6.2 ROUNDING OF NUMBERS
When a number is to be rounded to a specific number of decimals, it shall always be rounded off in
one step to the number of figures that are to be recorded and shall not be rounded in two or more steps of successive rounding. In absolute terms, when the figure to the right of last place to be retained is 5 or greater, the figure in the last place to be retained should be increased by 1. If the figure to the right of the last place to be retained is less than 5, the figure in the last place retained should be unchanged.
6.3 DISCRIMINATION
The rounding and discrimination requirements set forth in this section may be applied to verify
compliance with the calculation procedures of this standard. The data in Table 1 should not be used to construe or imply accuracy requirements or the capabilities (discrimination) of instrumentation used to furnish the measurements.
Where used to verify conformance to calculation procedures, the accounting hardware that displays or prints results from calculations shall have at least 32 bit binary word length or be capable of enough digits to preserve the resolution and display the maximum quantity required for the application – typically, this is
10 digits or better. In certain situations, such as with on-line real time calculations that are required by process measurement instrumentation, the available equipment may not have this capacity. In such cases, rounding and discrimination levels should be as close to the standard as the computing hardware will allow.
7 Observed Data (Input, Direct, or Primary)The input or observed data in Table 2 must be gathered as a first step in the calculation process. This
document does not address how these data are obtained. That information is found in the referenced publications listed in Section 2, and it is assumed, for the purpose of this document, that all such data have been obtained in accordance with these referenced publications. It should be understood that the observed data must be gathered concurrently. In other words, the level gauge, water cut, temperature, and so forth should all be taken at the same time for inclusion on the same measurement ticket or ullage report.
Table 2 - Observed Data
Shore Tanks Marine Vessel’s Tanks
Recorded reference gauge heighta Recorded reference gauge heighta Observed reference gauge heighta Observed reference gauge heighta Innage or ullage or liquid level Innage or ullage of liquid level Innage or ullage of free water level Innage or ullage of free water level
Average liquid temperature ºF or ºC Average liquid temperature ºF or ºC Observed density @ sample temperature Observed density @ sample temperature Percentage of sediment and water Percentage of sediment and water Ambient air temperature Forward draft reading
After draft readingList
a These data points do not have any direct impact on the calculation process. However, they can impact the calculation process indirectly and are usually recorded at this time.
8 Calculated Data (Indirect or Secondary)The data points presented in Table 3 are necessary for the calculation process and are calculated or
extracted using the input data from the previous section.
Table 3 - Calculated Data
Shore Tanks Marine Vessel’s Tanks
Density @ standard temperature Vessel’s trim
Floating roof adjustment or correction Density @ standard temperature Tank shell temperature correction Trim correction and list correction Total observed volume Total observed volume
Free water volume Free water volume
Gross observed volume Gross observed volume
Correction for temperature of liquid Correction for temperature of liquid
Gross standard volume Gross standard volume
Sediment and water (volume or factor) Sediment and water (volume or factor) Net standard volume Net standard volume
Mass or weight (See Section 12) Mass or weight (See Section 12)
9 Calculation of Gross Observed Volume (GOV)The calculation process for shore tanks and marine tank vessels only differs up to the point of
calculating gross observed volume (GOV). From this point on, the calculations are the same.
Refer to Annex A for examples of shore tank and marine vessel tank calculations.
9.1 SHORE TANKS
To calculate the GOV for shore tanks, deduct any free water (FW) from the total observed volume
(TOV) and multiply the result by the tank shell temperature correction (CTSh); then, apply the floating roof adjustment (FRA), where applicable.
GOV = [(TOV - FW) x CTSh] FRA
9.1.1 Total Observed Volume (TOV)
The TOV is obtained from the shore tank’s capacity table and is entered with the observed innage or
ullage.
9.1.2 Adjustment for the Presence of Free Water (FW) and Tank Bottom SedimentsIt is necessary to determine the amount of FW and bottom sediments, if any, before and after each
product movement into or out of a tank so that the appropriate corrections can be made. This adjustment
(FW) will always be in the form of a volumetric deduction.
9.1.3 Correction for the Effect of Temperature on the Steel Shell of the Tank (CTSh)
Any tank, when subjected to a change in temperature, will change its volume accordingly. Assuming
that they have been calibrated in accordance with API MPMS Chapter 2, upright cylindrical tanks have
capacity tables based on a specific tank shell temperature. If the observed tank shell temperature differs from the capacity table tank shell temperature, the volumes extracted from that table will need to be corrected accordingly.
Storage tanks differ from test measures in size and wall thickness. Differences also occur because the tanks cannot readily be sheltered from the elements. Therefore, ambient temperatures as well as product temperatures must be considered when calculating an appropriate correction for the effect of temperature on the shell of the tank. The correction factor for the effect of temperature on the shell of the tank is called CTSh and may be calculated by the following:
Cross-sectional area correction,
CTSh = 1 + 2άΔT + ά2ΔT2
Where: ά = Linear coefficient of expansion of the tank shell material [see note 4]
ΔT = Tank Shell Temperature (TSh) – Tank Shell Reference Temperature (TShREF)
Note 1: Tank Shell Reference Temperature (TShREF) is the tank shell temperature for which the
capacity table volumes were calculated to; typically 60°F, 15°C and 20°C, although other
temperatures are used.
Note 2: The Tank Shell Reference Temperature (TShREF) is usually stated on the capacity table. If this is not the case, contact the company that generated the table. Some capacity tables make reference to an operating product temperature; this should not be confused with the Tank Shell Reference Temperature (TSh REF), which is a tank shell temperature.
Note 3: When calculating ΔT it is important to maintain the arithmetic sign as this value can be positive
or negative and must be applied as such in the CTSh formula.
Note 4: See Table B3 in Annex B for linear expansion coefficients of various metals.
9.1.3.1 For non-insulated metal tanks, the temperature of the shell may be computed as follows (refer to
Annex B):
TSh = [(7 x TL) + Ta ] 8
Where:
TL = liquid temperature.
Ta = ambient temperature.
Note: Ambient air temperature surrounding a storage tank can vary widely. For practical operational
purposes the recommended methods of taking this temperature are: A temperature device carried by the measurement technician into the tank area when
gauging tanks. Take at least one temperature reading in a shaded area. If more than one temperature is taken, average the readings. Shaded external thermometers permanently mounted in the tank farm area.
Local on-site weather stations.
All on site temperature devices, used to record ambient air temperature for the calculation of tank
shell correction factors during custody transfer shall have their accuracy of plus or minus two degrees Fahrenheit verified every three months.
Where the uncertainty of the ambient air temperature is plus or ± 5ºF (± 2.5ºC), the effect on
calculating the tank shell correction factor is 1 in 100,000.
Temperature readings are to be taken 3 feet [1 meter] from any obstructions or the ground.
Additionally, allow sufficient time for temperature readings to stabilize.
9.1.3.2 For insulated metal tanks, the temperature of the shell may be taken as closely approximating the
adjacent liquid temperature, in which case, TSh = TL.
9.1.3.3 The third dimension needed to generate volume - height - is a function of gauging and should be
considered separately. The volumes reflected on tank tables are derived from area multiplied by incremental height. Therefore, K- factors for correction of areas have the same ratio as volume corrections and may be applied directly to tank table volumes. For an example calculation see Annex B.
9.1.3.4 The shell temperature correction factor is to be applied to volumes obtained from capacity tables
that are at standard conditions and are unrelated to the corrections designed to account for volume expansion and contraction of the product itself. Depending upon certain requirements, this shell temperature correction factor may be built into the capacity table for a specific operating temperature.
9.1.3.5 The application of a CTSh does not apply in the following circumstances
To lease tanks and other such small tanks of 5,000 bbls (795 m3)or less
Marine vessels
9.1.4 Floating Roof Adjustments and Corrections (FRC & FRA)
There are two types of floating roofs – internal and external; however, the calculation process to
determine the floating roof adjustment or correction is the same for both types of roofs. The determination of the correction, however, can be addressed in one of two ways:Floating Roof Adjustment (FRA) –This method is used when a correction for the roof has been
calculated into the tank capacity table using a reference density. A secondary correction (or
adjustment) must therefore be calculated for any difference between the reference density and the
observed density at tank temperature. This correction can be positive or negative.
b. Floating Roof Correction (FRC) – In this situation the tank capacity table has not been adjusted for
the roof; therefore a volume, equivalent to the entire weight of the roof, must be calculated and applied as a correction. This correction is always negative and is calculated by dividing the weight of the floating roof by observed density at tank temperature.
Examples of floating roof adjustment and correction calculations can be found in Annex C
Note: No floating roof correction will be accurate if the liquid level falls inside the floating roof’s critical
zone regardless of table style. While the results can be displayed they should not be used for custody transfer.
Note: If a significant amount of water, ice, or snow is present on a floating roof, it should either be
removed or its weight estimated and calculated into the roof correction.
Note: Roof corrections are not applicable for volumes below the critical zone.
9.2 MARINE VESSEL’S TANKS
To calculate the GOV for marine vessel’s tanks, deduct the FW volume from the TOV.
GOV = TOV - FW
In the event of a volumetric trim or list correction as per 9.2.2 Item a, the calculation is as follows:
GOV = (TOV ± trim or list correction) - FW (see note)
Note: Refer to 9.2.3.
9.2.1 Total Observed Volume (TOV)
The TOV is obtained from the vessel’s capacity tables, which are entered with one of the following:
a. The observed ullage or innage, if the trim and/or list corrections are a volumetric adjustment. The
amount of trim and/or list correction will need to be applied to the TOV quantity to arrive at a trim and/or list corrected TOV.
b. The trim and/or list corrected ullage or innage.
c. The observed ullage or innage and the vessel’s trim. Some capacity tables show varying TOV values for the same gauge under differing conditions of trim.
9.2.2 Trim Correction
The trim correction is applied to compensate for the change in liquid level due to the longitudinal plane
of the vessel not being horizontal.
Subtract the forward draft reading from the after draft reading. If the trim is positive (that is, the after draft reading is larger), the vessel is said to be “trimmed by the stern.” If the trim is negative (that is, the forward draft reading is larger), the vessel is said to be “trimmed by the head.” Note the following:
a. The trim correction is found in the vessel’s calibration tables and is usually a correction to the
observed innage/ullage. However, it can be a volumetric adjustment to the TOV.
b. Trim corrections can be either positive or negative. The trim correction table will state how this correction is to be applied.
c. If trim corrections are not available, it may be possible to calculate this value. Refer to API MPMS
Chapter 2.8A, Section 10.4.
9.2.3 List Correction
List correction is applied to compensate for the change in liquid level due to the vertical plane of the
vessel not being perpendicular to the horizontal. A vessel’s list is usually read from its inclinometer. However, if such an instrument is not available or there is doubt as to its accuracy, then the list can be calculated from the port and starboard amidships draft readings. Refer to Figure 1 for this calculation. Note the following:
a. List corrections are applied in the same manner as are trim corrections.
b. List corrections can be either positive or negative. The list correction table will state how this correction is to be applied.
c. If list corrections are not available, it may be possible to calculate this value. Refer to API MPMS
Chapter 2.8A, Section 10.4.
Insert Figure 1 - Method to Calculate Vessel’s List Using Amidships Draft Readings
(This is the same as is in the current Edition and will not be changed for this edition)
9.2.4 Combining Trim and List Corrections
Caution must be exercised when applying trim and list corrections collectively. In many cases these
corrections are only applicable when the other condition does not exist. For information on the calculation procedure for combined trim and list corrections, refer to API MPMS Chapter 2.8A, Section 10.4.
9.2.5 Free Water Volume (FW)
FW volume is obtained from the vessel tank capacity tables, which are entered with the FW innage or
ullage. As with any liquid in a marine vessel’s tank, FW is subject to the effects of trim and list, and the previously referenced trim and list corrections are applicable to FW, provided that the FW is touching all bulkheads of the tank. If the FW does not touch all tank bulkheads, a wedge condition exists. The
formula for calculating whether or not a wedge condition exists, the application of wedge tables/formulae, and the calculation of the wedge formula can be found in API MPMS Chapter 17.4.
10 Calculation of Gross Standard Volume (GSV) and Total Calculated Volume (TCV) -Shore Tanks and Marine Vessel’s Tanks10.1 GROSS STANDARD VOLUME (GSV)
The GSV is calculated by multiplying the GOV by the correction for the effect of temperature and
pressure on the liquid (or the volume correction factor).
GSV = GOV x CTPL
10.2 CORRECTION FOR THE EFFECT OF TEMPERATURE AND PRESSURE ON A LIQUID (CTPL)
or VOLUME CORRECTION FACTOR (VCF)
If a quantity of oil is subjected to a change in temperature, its volume will increase as the temperature
rises or decrease as the temperature falls. The volume change is proportional to the thermal coefficient of expansion of the liquid, which varies with density (API gravity) and temperature. The correction factor for the effect of the temperature and pressure on a volume of liquid is called CTPL, CTL or VCF. The function of this correction factor is to adjust the volume of liquid at observed temperature to its volume at a standard temperature. The most common standard temperatures are 60ºF, 15ºC, and 20ºC (68ºF).
These correction factors can be obtained from API MPMS Chapter 11.1, the Adjunct to ASTM D1250,
or the Adjunct to IP 200. These computer programs or tables are entered with the observed average temperature and API gravity at 60ºF, a density at 15ºC, a relative density at 60ºF/60ºF, or a coefficient of thermal expansion. To determine which table is applicable, refer to Table 4.
Table 4 - CTPL Factors
Table Product Temp Entry
6A Generalized crude oil ºF API gravity @ 60ºF
6B Generalized products ºF API gravity @ 60ºF
6C Individual & special applications ºF Thermal expansion coefficient
6D Generalized lubricating oils ºF API gravity @ 60ºF
24A Generalized crude oil ºF Relative density @ 60/60ºF
24B Generalized products ºF Relative density @ 60/60ºF
24C Individual & special applications ºF Thermal expansion coefficient
54A Generalized crude oil ºC Density @ 15ºC
54B Generalized products ºC Density @ 15ºC
54C Individual & special applications ºC Thermal expansion coefficient
54D Generalized lubricating oils ºC Density @ 15ºC
60A Generalized crude oil ºC Density @ 20ºC
60B Generalized products ºC Density @ 20ºC
60C Individual & special applications ºC Thermal expansion coefficient
60D Generalized lubricating oils ºC Density @ 20ºC
ASTM D4311 Asphalt to 60ºF, Table 1 ºF API gravity @ 60ºF, Table A or B ASTM D4311 Asphalt to 15ºC, Table 2 ºC Density @ 15ºC, Table A or B
Additionally, ASTM D1555 and D1555M (Metric edition), which tabulates CTL (VCF) for various
aromatic hydrocarbons.
Many products, especially petrochemicals, may have specific volume correction factor tables,
developed by the manufacturer. These are usually in the form of product specific tables of CTL (VCF), showing the factor at observed temperatures, which must be applied to obtain the volume at standard temperature; or, a volume correction factor, per degree difference in observed temperature. While these individual tables can have their own parameters and table entry requirements, their application is the same.
The use of these tables should be by mutual agreement of all parties concerned.
10.3 TOTAL CALCULATED VOLUME (TCV)
Total calculated volume (TCV) is determined by adding the Gross Standard Volume (GSV) to the Free
Water (FW)
TCV = GSV + FW
11 Calculation of Net Standard Volume (NSV)11.1 NET STANDARD VOLUME (NSV)
To calculate NSV, multiply the GSV by the CSW.
NSV = GSV x CSW
This, can be expanded to:
NSV = GSV x [(100 – S&W %) 100]
11.2 CALCULATION OF THE CORRECTION FOR SEDIMENT AND WATER (CSW)
To calculate the CSW value, the percentage of S&W must be known. Deduct the S&W percentage
value from 100, thus determining the NSV as a percentage of the GSV, divide this by 100, and multiply the GSV by it.
CSW = (100 - S&W %) 100
On multiple tank shipments, NSV can be calculated on a tank-by-tank basis if the individual S&W
values are known. However, it can be calculated on a grade or parcel basis if the S&W was analyzed on an appropriate representative sample.NOTE: Crude oil and some liquid petroleum products contain sediment and water suspended or entrained throughout
1.11.00.9
###
that fluid. The quantity of sediment and water is determined by laboratory analysis of a representative sample and is expressed as a percentage, usually volume percent. For information on how sediment and water analysis is performed, refer to API MPMS Chapter 10 or its ASTM equivalents.
11.3 CALCULATION OF THE VOLUME OF SEDIMENT AND WATER (S&Wvol)
It is frequently necessary to calculate the actual volumetric value of S&W. This can be achieved by
subtracting the net standard volume (NSV) from the Gross Standard Volume (GSV).
S&WVOL = GSV - NSV
12 Calculation of Mass (Weight in Vacuum) and Weight (Weight in Air)12.1 INTRODUCTION
While the terms mass and weight have there own definitions within the scientific community, when
referred to in this document, mass will refer to weight in vacuum (vacuo) and weight will refer to weight in air. If the same material is measured in a vacuum and then in air, the measured quantity in air will be lighter than that of the measured quantity in vacuum by an amount equal to the volume of air displaced by the material being measured. In other words the weight measured in air is affected by the “buoyancy” of the air surrounding the object.
The routines, however, for calculating mass and weight are the same, they just use different factors.
12.2 CALCULATION METHODS
There are two common methods utilized to calculate mass and/or weight, both of which are capable of
calculating either of them.
12.2.1 Volume at Standard Temperature to Mass/Weight Method
This method corrects the volume at the observed temperature to the volume at the standard
temperature by applying a CTPL or CTL (VCF) after which the weight/mass is obtained by multiplying the standard volume with the density at the same standard temperature. If mass is required use the density in vacuum. If weight is required use the density in air
12.2.2 Volume at Observed Temperature to Mass/Weight
This method adjusts the density at standard temperature to its density at observed temperature by use of
a thermal expansion coefficient per degree, then, multiplying it by the volume at observed temperature to obtain mass or weight. If mass is required use the density in vacuum. If weight is required use the density in air
12.2.3 Calculation of Gross Standard Weight and Net Standard Weight
Gross Standard Weight (GSW) and Net Standard Weight (NSW) are calculated by multiplying the GSV or
NSV by the appropriate density in air. NSW = NSV x Density in air
GSW = GSV x Density in air
12.2.4 Calculation of Gross Standard Mass and Net Standard Mass
Gross Standard Mass (GSM) and Net Standard Mass NSM are calculated by multiplying the GSV or NSV
by the appropriate density in vacuum. NSM = NSV x Density in vacuum
GSM = GSV x Density in vacuum
12.3 CONVERTING BETWEEN MASS AND WEIGHT
As the difference is equal to the weight of the volume of air displaced by the object being weighed, high
density materials will displace less air than low density materials; therefore, the difference between weight in air and weight in vacuum varies with density and will have the greatest impact on low density materials. While this difference is not large, it is measurable and typically impacts the third and fourth decimal place of the density, by an amount shown in the table below.Table 5 – Mass to Weight Density Corrections
Density Range(kg/m3)
Density Correction(kg/m3)
Less than 996.6996.6 – 1,663.5Greater than 1,6635
The majority of petroleum based materials are in the density range of 600.0 to 996.6 kg/m3, therefore, the most common correction is 1.1; however, densities above 996.6 kg/m3 are not uncommon, especially in the chemical industry. When adjusting a density in vacuum to its corresponding density in air, the correction is subtracted. When adjusting a density in air to its corresponding density in vacuum, the
correction is added.While the use of Table 5 to adjust densities for mass to weight calculations and vice versa is
convenient and quick, especially for field applications, API MPMS Chapter 11.5.3 specifies a formula for making this conversion, which is reproduced below.
The following equation expresses the relationship between Density in Vacuum in kg/m3 at 15 C and
Density in Air at 15 C in kg/m3
15 in kg/m3
= 1.000149926 D15
Where: D 15
= Density in Air
D15 = Density in Vacuum
In the event of a dispute or when greater discrimination is required than is provided for by Table 5, the
formula specified in API MPMS Chapter 11.5.3 shall be used.
13 Direct Mass MeasurementSome measurement methods, for example hydrostatic tank gauges, determine mass by measuring
liquid head rather than liquid level. The calculation algorithms used by these methods may include corrections for the effect of temperature and pressure on the liquid (10.2), for the effect of liquid density on the floating roof (9.1.4), or the effect of temperature on the shell of the tank (9.1.3). In such cases,
these corrections should not be duplicated. For calculation procedures, refer to API MPMS Chapter 16.2.
14 Calculation Sequence14.1 GENERAL
It is outside the scope of this document to instruct the user in the procedures and techniques
necessary to obtain all the observed information that will be needed in order to calculate a net volume. It is the user’s responsibility to obtain that information from the standards referenced earlier. While there are some precautionary notes in the text of this document, it is assumed that the user will come to this standard with all the observed information necessary to begin to calculate net volumes. The information needed is liquid level, FW level, product temperature, ambient temperature, density, and S&W percentage. It will also be necessary to have the capacity table and applicable correction factor tables or
subroutines. Any deduction that is inappropriate for a particular application will be a zero deduction, and
any correction that is inappropriate will be held at 1.00000. The calculation routine will be the same.
14.2 VOLUME AT STANDARD TEMPERATURE TO MASS/WEIGHT CALCULATION PROCEDURE
The calculation sequence follows that of the preceding sections. The flow is as follows (see Figures A-
1 and A-2):
TOV GOV GSV NSV NSW
or
TOV GOV GSV NSV NSM
a. With the liquid level or gauge, enter the capacity table and record the TOV, as recorded in the table.
b. Subtract any gauged FW volumes. The FW volume is obtained by entering the capacity table with the gauged FW level.
c. Apply the CTSh to arrive at the GOV.
d. Correct this quantity for any applicable FRA or FRC.
e. Correct the GOV to standard temperature. This is done by multiplying the GOV by the CTPL to arrive at the GSV.
f. Adjust for any measured amount of S&W. This is done by multiplying GSV by the CSW. g. If net standard weight [NSW] is required, multiply the result from Item f. the density in air
h. If net standard mass [NSM] is required, multiply the result from Item f. the density in vacuum
The mathematical formulae for the various required values can be expressed as follows:
GSV = {[(TOV - FW) x CTSh] FRA} x CTPL
GSW = {[(TOV - FW) x CTSh] FRA} x CTPL x Density (in air or vacuum as required)
NSV = {[(TOV - FW) x CTSh] FRA} x CTPL x CSW
NSW = {[(TOV - FW) x CTSh] FRA} x CTPL x CSW x Density (in air or vacuum as required)
Chain calculations must be performed. Only the final result in the calculation is to be rounded. If it is
necessary to report any intermediate values, the figure should be rounded as required in Section 5; however, the rounded figure is not to be inserted into the calculation sequence. See Annex A for examples of shore tank and marine vessel tank calculations.
14.3 VOLUME AT OBSERVED TEMPERATURE TO MASS/WEIGHT CALCULATION PROCEDURE
The calculation sequence follows that of the preceding sections.
TOV GOV Mass or Weight
a. With the liquid level or gauge, enter the capacity table and record the TOV, as recorded in the table.
b. Subtract any gauged FW volumes. The FW volume is obtained by entering the capacity table with the gauged FW level.
c. Apply the CTSh to arrive at the GOV.
d. Correct this quantity for any applicable FRA or FRC.
e. Correct the GOV to mass or weight. This is done by multiplying the GOV by the density in air at observed temperature to arrive at the weight or density in vacuum at observed temperature to arrive at the mass.NOTE: This method is not normally used on crude oils or other materials where net standard volume [NSV] or netstandard weight [NSW] is required. Should this be required, the density at standard temperature should be applied to the mass or weight, as appropriate, to arrive at gross standard volume [GSV].
The mathematical formulae for the various required values can be expressed as follows:
GOV = {[(TOV - FW) x CTSh] FRA}
Mass or Weight = {[(TOV - FW) x CTSh] FRA} x Density at Observed Temperature (in air or vacuum as
required)
Density at standard temperature is converted to density at observed temperature as follows:
( Cs)
t s t
Where:
ρt = density at measured temperature
ρs = density at standard temperature
= difference in temperature (standard - measured)t
Cs = coefficient of thermal expansion per degree
Chain calculations must be performed. Only the final result in the calculation is to be rounded. If it is
necessary to report any intermediate values, the figure should be rounded as required in Section 6; however, the rounded figure is not to be inserted into the calculation sequence. See Annex A for examples of shore tank and marine vessel tank calculations.
15 Calculation of Transferred Volumes for Custody Transfer15.1 GENERAL
The calculation routines specified in this document are specific to the quantity of material in a tank whose
contents are not in motion. The calculation of transferred volumes for custody transfer typically involves performing the same calculation before and after a transfer and determining the difference. If multiple tanks are involved this process is repeated for each tank and the sum of the quantity transferred from each tank is the total quantity transferred. However, when multiple tanks are involved, there are numerous variations on how the total transferred quantity can be calculated. In many cases the GSV is
calculated from each tank’s opening and closing measurements, and then additional calculations to NSV
and mass or weight are made collectively to this quantity. Alternatively, the individual opening and closing readings can be calculated to NSV, mass or weight and totalized accordingly. The differences resulting from these variations are usually very small and it is not the intent of this standard to specify a single method for this. Examples A1 and A2 in Annex A outline two of the more commonly used methods; however, these should not be construed as the only acceptable methods. The method used for custody transfer should be that as agreed to by the commercial parties to the transaction.
15.2 SMALL LEASE TANKS
Lease tanks differ from storage tanks not only in size but in gauging procedure. Therefore, it is
necessary to establish unique calculation procedures for lease tanks. This procedure is applicable to lease tanks of 5,000 barrels (795 m3) or less and assumes that the clearance sample has verified merchantable oil at least 4 inches below the tank outlet. The CTSh is not significant to these situations
and should not be applied.
15.2.1 Transferred Volume Calculation Procedure for Lease Tanks
The following are the procedures for calculating transferred volumes for lease tanks:
a. With the liquid level or gauge, enter the capacity table and record the TOV for the opening gauge.
b. Correct for the temperature of the oil. This is done by multiplying the answer from Item a. by the
CTPL, arriving at the GSV, and rounding appropriately.
c. With the liquid level or gauge, enter the capacity table and record the TOV for the closing gauge.
d. Correct for the temperature of the product. This is done by multiplying the answer from Item c. by the
CTPL, arriving at the GSV, and rounding appropriately. e. Subtract the closing GSV from the opening GSV.
f. The last correction shall be to adjust for any measured amount of S&W. This is done by multiplying
the ∆GSV obtained from Item e. by the CSW and rounding appropriately.
15.3 VOLUMETRIC SHRINKAGE
Volumetric shrinkage occurs when light hydrocarbons are mixed with much heavier hydrocarbons. The
tables and calculation routines are specified in API MPMS Chapter 12.3. It is not normal practice to
include these quantities in custody transfer calculations as the volumes lost are not available again, except through refining. Any adjustments made as a result of volumetric shrinkage are strictly upon agreement of the commercial parties involved.
Note: Mass or weight is not affected by volumetric shrinkage.
16 Miscellaneous16.1 PRECAUTIONS WHEN USING AN AUTOMATIC SAMPLER
When automatic sampling systems are employed for product transfer, tanks with varying densities
(crude oil systems, for example) will need to accumulate base data differently than for transfers that do not include the use of an automatic sampler. While the volume calculation procedures for movements into a tank involving an automatic sampling system will be the same, the method of collecting the base information will be different. (Movements out of a tank are less affected as there is less blending of densities taking place). However, it may be necessary to report the density, as determined from the automatic sampling system, somewhere on the measurement ticket or report. Regardless, it will still be necessary to sample the tank before and after a receipt because of the following:
a. At the beginning of the transfer, there is nothing in the sampler and therefore nothing on which to base
opening measurements.
b. After the transfer, the incoming product has been blended with whatever was in the tank. In order for the CTPL and FRA to be correct, they will have to be based on the density of the product as found in the tank.
c. The tank’s FW level must be left the same on the closing report as on the opening report. All deducted water volumes should come from the sampler and be accounted for in the form of correction for S&W (CSW).
d. S&W are usually only deducted on crude oil cargoes. Petroleum products are not usually corrected for S&W unless required as a commercial condition or other specific requirement; therefore net standard volume = gross standard volume.
16.2 INTERRELATION OF UNITS
It is frequently necessary to convert from one type of unit to another using a conversion factor. These
conversion factors are found in API MPMS Chapter 11.5 of which there are three subchapters: Chapter 11.5.1 - Conversions of API Gravity at 60 F
Chapter 11.5.2 - Conversions for Relative Density (60/60 F)
Chapter 11.5.3 - Conversions for Density in vacuum at 15 C
These three standards replace the Density/Weight/Volume Intraconversion tables formerly located in
API MPMS Chapter 11.1, Volumes XI/XII. There are separate conversion factors for mass and weight,
depending upon which one is required.
Due to the complexity of these interrelations there is frequently more than one way of performing these
conversions and this standard does not attempt to define any specific routines for converting from one unit to another; however, the user should be guided by the following:
Conversion units that are “exact by definition” are to be considered primary and shall be used whenever possible
Conversion processes shall not produce a result that contradicts an “exact by definition” value
The use of multiple conversion factors should be avoided if possible. If this cannot be avoided the process that uses the least number of conversion factors shall be used.
ANNEX A –EXAMPLES OF SHORE TANK AND MARINE VESSEL TANK CALCULATIONS (NORMATIVE)
Example A-1 Custody Transfer Flow Chart – Shore Tanks with Automatic SamplerOPENING GAUGE CLOSING GAUGE
TOTAL
OBSERVED VOLUME
Minus Free
Water
Multiply by CTSh
Plus or Minus Floating Roof Adjustment or Correction
TOV
DEL/REC
TOTAL
OBSERVED VOLUME
Minus Free
Water
Multiply by CTSh
Plus or Minus Floating Roof Adjustment or Correction
Notes:
1. For multiple tank movements add each tank’s delivered or received GSV and proceed as shown.
2. Facilities that apply the
vessel’s free water to the transferred quantity shall apply this immediately prior to the CSW correction
3. Tank free water (FW) on opening and closing must remain constant.GROSS
OBSERVED VOLUME
GOV
DEL/REC
GROSS
OBSERVED VOLUME
Multiply by CTPL
(VCF)
Multiply by CTPL
(VCF)
GROSS
STANDARD VOLUME
GROSS
STANDARD VOLUME
TOTAL GSV
DELIVERY or RECEPT
Multiply by Density in Air
Multiply by Density in Vacuum
GROSS STANDARD WEIGHT
GROSS STANDARD MASS
Multiply by Correction for
Sediment & Water (CSW)
TOTAL NSV
DELIVERY or RECEPT
Multiply by Density in Air
Multiply by Density in Vacuum
NET STANDARD WEIGHT
NET STANDARD MASS
Example A-2 Custody Transfer Flow Chart – Share Tank(s) with Individual Tank SamplesSingle Tank Calculation
OPENING GAUGE CLOSING GAUGE
Note: For multiple tank
movements add each
tank’s delivered orTOTAL
OBSERVED VOLUME
Minus Free
Water
TOV
DEL/REC
TOTAL
OBSERVED VOLUME
Minus Free
Water
received quantity as
appropriateMultiply by CTSh
Multiply by CTSh
Plus or Minus Floating
Roof Adjustment or
Correction
Plus or Minus Floating
Roof Adjustment or
Correction
GROSS
OBSERVED VOLUME
GOV
DEL/REC
GROSS
OBSERVED VOLUME
Multiply by CTPL
(VCF)
Multiply by CTPL
(VCF)
GROSS
STANDARD VOLUME
GSV
DEL/REC
GROSS
STANDARD VOLUME
Multiply by Correction for
Sediment & Water (CSW)
Multiply by Correction for
Sediment & Water (CSW)
NET
STANDARD VOLUME
NSV
DEL/REC
NET
STANDARD VOLUME
Density
in Air
Density in
Vacuum
Density
in Air
Density in
Vacuum
435,218.32 435,218.32
1.00032 435,203.17
0.98676429,478.47
0.9988
428,963.09
NET
STANDARD WEIGHT
NSW
DEL/REC
NET
STANDARD WEIGHT
NET
STANDARD MASS
NSM
DEL/REC
NET
STANDARD MASS
Example A-3
Shore Tank Calculation
Using
Volume at Standard Temperature to Mass or Weight Calculation Procedure
Analytical and Observed Data
Liquid level gauge 46’ 06 1/4”
Free water gauge 00’ 10 3/4”
API gravity @ 60ºF 33.7 (rounded from 33.69) Liquid temperature ºF 88.3
Ambient temperature ºF 71.5
Temperature of tank shell ºF (TSh) 86.0 (rounded from 86.2) Sediment and water percent 0.12%
CalculationCalculated or Derived Data Symbol Reported Unit Barrels or
Long TonsRunning Calculation (Not Reported)
Total observed volume1 TOV1
Free waterGross observed volume2
FW GOV2 -154.37435,063.95
-154.37435,063.95
Correction for temperature of shell CTSh 435,203.1704643
Floating roof adjustmentGross observed volume
FRA +37.89435,241.06
+37.89435,241.0604643
Correction for temperature ofLiquid (Table 6A)
Gross standard volumeCTPLGSV
429,478.4688233
Correction for sediment and water4 CSW
Net standard volume NSV 428,963.094663
Density in air (Long tons per bbl) 0.13373 (API MPMS Chapter 11.5.1)
Net standard weight (long tons) NSW 57,365.235 57,365.23464883
Alternate Calculation from Net Standard Volume if Net Standard Mass is required:
Density in vacuum (Long tons per bbl) 0.13390 (API MPMS Chapter 11.5.1)
Net standard mass (long tons) NSM 57,438.158 57,438.15837493
NOTES:
1 Quantity from the tank capacity table using the liquid level gauge to enter the table. For this example, it is assumed that any correction to the gauge, due to expansion or contraction of the tape itself, has already been made. This issue is not addressed in this standard. The user should refer to the tape manufacturer’s instructions for specific details.
2 Gross observed volume, uncorrected for the temperature of the tank shell and floating roof adjustment.
3 As displayed on a 12-digit calculator. Actual discrimination is determined by the calculating capacity of the calculation hardware.
4 Refer to 11.3 to calculate the volumetric value for sediment and water.
Example A-4
Marine Vessel Tank Calculation
Using
Volume at Standard Temperature to Mass or Weight Calculation Procedure
35,118.65
34,982.93 34,982.9342.8034,940.13 34,940.13
34,471.48
3
34,412.88
1289561 1289561
1.00016 1284329
0.98676 1263586
Analytical and Observed Data
Liquid level gauge (ullage) 4’ 06 1/4”
Free water gauge (ullage) 55’10 3/4”
API gravity @ 60ºF 27.1 (rounded from 27.14) Liquid temperature ºF 91.1
Sediment and water percent 0.17% Forward draft 36’ 06” After draft 38’ 00” Trim (by the stern) 1’ 06” List (vessel upright) No list
Calculation
Calculated or Derived Data Symbol Reported Unit Barrels or RunningLong Tons Calculation
(Not Reported)
Total observed volume1
Trim correction (volumetric)2
TOV1
Trim2
35,118.65-135.72
Total observed volume TOVFree water (by wedge) FWGross observed volume GOVCorrection for temperature of liquid CTPL 0.986 59 (Table 6A)Gross standard volume GSV 34,471.48419773
Correction for sediment and water4 CSW 0.998
Net standard volume NSV 34,412.88267453
Density in air (Long tons per bbl) 0.13930 (API MPMS Chapter 11.5.1)
Net standard weight (long tons) NSW 4,793.715 4,793.71455655 3
Alternate Calculation from Net Standard Volume if Net Standard Mass is required:
Density in vacuum (Long tons per bbl) 0.13947 (API MPMS Chapter 11.5.1)
Net standard mass (long tons) NSM 4,799.565 4,799.564746613
NOTES:
1 Quantity from the vessel’s tank capacity table using the liquid level ullage gauge to enter the table.
2 Not all trim (or list) corrections are volumetric. Many are linear adjustments that are made to the observed ullage. In this case, the adjustment would be made before entering the vessel’s capacity table and a volumetric adjustment would not be necessary. If a volumetric list correction was applicable, it would be applied at this point in the calculation.
3 As displayed on a 12-digit calculator. Actual discrimination is determined by the calculating capacity of the calculation hardware.
4 The volumetric value for sediment and water is determined by subtracting the net standard volume from the gross standard volume.
Example A-5
Shore Tank Calculation of Volume at 15ºC and Weight of p-Xylene using ASTM D1555M
Analytical and Observed Data
Liquid level gauge 4606 mm
Free water gauge 10 mm Density at 15ºC kg/l (air) 0.8643 kg/l Liquid temperature ºC 22.3ºC Ambient temperature ºC 18.0ºC
Temperature of tank shell ºC (TSh) 22.0ºC (rounded from 21.8 ºC)
CalculationCalculated or Derived Data Symbol Reported Unit Litres / kg Running Calculation
(Not Reported)
Total observed volume1 TOV1
Free waterGross observed volume2
FW GOV2 -54371284124
-54371284124
Correction for temperature of shell CTSh 1284329.459843
Floating roof adjustmentGross observed volume
FRA -37891280540
- 37891280540.459843
Correction for temperature of [VCF]Liquid (Table ASTM D1555)Gross standard volume at 15ºC
CTPLGSV
1263586.104153
0.86431092117
1289561 1289561
1.00013 1289729
1277710
0.7440950616
Density in air at 15ºC kg/lWeight
1092117.469813
NOTES:
1 Quantity from the tank capacity table using the liquid level gauge to enter the table. For this example, it is assumed
that any correction to the gauge, due to expansion or contraction of the tape itself, has already been made. This issue is not addressed in this standard. The user should refer to the tape manufacturer’s instructions for specific details.
2 Gross observed volume, uncorrected for the temperature of the tank shell and floating roof adjustment.
3 As displayed on a 12-digit calculator. Actual discrimination is determined by the calculating capacity of the calculation hardware.
Example A-6
Shore Tank Calculation of Volume at 15ºC, Mass and Weight of MTBE using
API MPMS Chapter 11.1/Adjunct to ASTM D1250/Adjunct to IP 200, Table 54C
Analytical and Observed Data
Liquid level gauge 5810 mm
Free water gauge None Found
Coefficient of thermal expansion 0.0014202 alpha per ºC Density in air at 15ºC kg/l 0.7429
Liquid temperature ºC 22.5ºC Ambient temperature ºC 12.0ºC
Temperature of tank shell ºC (TSh) 21.0ºC (rounded from 21.1 ºC)
CalculationCalculated or Derived Data Symbol Reported Unit Litres / kg Running Calculation
(Not Reported)
Total observed volume1 TOV1
Correction for temperature of shell CTSh 1289728.642933
Floating roof adjustmentGross observed volume
FRA -37891285940
- 37891285939.64293 3
Correction for temperature of [VCF]Liquid CTPL 0.99360 (API MPMS Chapter 11.1, Table 54C)2
Gross standard volume at 15ºC GSV 1277710 1277709.629213
Density at 15ºC kg/l (air) 0.7429
Weight (in air) 949210 949210.48354 3
For Conversion to Mass (weight in vacuum)
Density at 15ºC kg/l (air) 0.7429
Density adjustment + 0.0011 (From Table 5 in Section 12.3) Density at 15ºC kg/l (vacuum) 0.7440
Gross standard volume at 15ºC GSV 1277709.629213
Density at 15ºC kg/l (vacuum)Mass (weight in vacuum) 950615.9641323
Notes:
1 Quantity from the tank capacity table using the liquid level gauge to enter the table. For this example, it is assumed that any correction to the gauge, due to expansion or contraction of the tape itself, has already been made. This issue is not addressed in this standard. The user should refer to the tape manufacturer’s instructions for specific details.
2 MTBE has a special application table, which is a function of the API MPMS Chapter 11.1/Adjunct to ASTM D1250/Adjunct to IP 200 “C” Tables; however, this example is applicable to any CTPL/VCF that derives form these “C” tables.
3 As displayed on a 12-digit calculator. Actual discrimination is determined by the calculating capacity of the calculation hardware.
ExampleA-7Shore Tank Calculation of the Weight of Benzene
Using
Coefficient of Thermal Expansion per Degree (Cs).
The Density at standard temperature is converted to Density at Measured temperature, which is then
applied to the measured volume to give mass or weight, as appropriate.
Analytical and Observed Data
1289561 1289561
1.00013 1289729
0.8756 1125969
0.88311275018 1275018.4026
Liquid level gauge 5810 mm Free water gauge None Found Density at 15ºC (air) kg/l 0.8831 kg/l (air) Thermal Density Coefficient / ºC 0.00100 kg/l per ºC Liquid temperature ºC 22.5ºC
Ambient temperature ºC 12.0ºC
Temperature of tank shell ºC (TSh) 21.0ºC (rounded from 20.8ºC)
CalculationCalculated or Derived Data Symbol Reported Unit Litres / kg Running Calculation
(Not Reported)
Total observed volume1 TOV1
Correction for temperature of shell CTSh 1289728.642932
Floating roof adjustmentGross observed volume
FRA -37891285940
- 37891285939.64293 2
Density at Obs. Temp. 22.5ºC kg/l (air)Weight (in air)
1125968.75134 2
Density at 15ºC, kg/l (air)Liters at 15ºC
t
Where:
( Cs)
s t
Note:
1 Quantity from the tank capacity table using the liquid level gauge to
ρt = density at measured temperature
ρs = density at standard temperature
= difference in temperature (standard - measured)
t
Cs = coefficient of thermal expansion per degree
Density at 15ºC 0.8831 kg/l (air) Expansion coefficient 0.00100 kg/l per ºC
ρt = 0.8831 + ([15.0 – 22.5] * 0.00100)
= 0.8831 + (-7.5 * 0.00100)
= 0.8831 – 0.00750
= 0.8756
enter the table. For this example, it
is assumed that any correction to the gauge, due to expansion or contraction of the tape itself, has already been made. This issue is
not addressed in this standard. The user should refer to the tape
manufacturer’s instructions for
specific details.
2 As displayed on a 12-digit calculator. Actual discrimination is
determined by the calculating
capacity of the calculation hardware.
ANNEX BEXAMPLE OF SHELL TEMPERATURE CORRECTION FACTORS FOR EXPANSION AND CONTRACTION OF UPRIGHT CYLINDRICAL STEEL TANKS DUE TO TEMPERATURE (NORMATIVE)
For mild steel tanks with a linear coefficient of expansion of 0.0000062/°F, use Table B1. For temperatures
outside the range of this table or for other coefficients expansion, use the formula in 9.1.3.
This table is applicable to tanks whose capacity tables were calculated at a reference tank shell
temperature of 60°F. For tanks with capacity tables calculated at a reference tank shell temperature other than 60°F, the table can still be used. However, it is necessary to subtract the reference temperature from the shell temperature and then add 60 to arrive at the temperature used to enter the table. It is important to pay attention to the algebraic signs (positive or negative) when performing this calculation.
B.1 Shell Temperature Correction Factors for Expansion and Contraction of Upright Cylindrical
Steel Tanks Due to Temperature
B.1.1 Tanks undergo expansion or contraction due to variations in ambient and product temperatures.
Such expansion or contraction in tank volume may be computed once the tank shell temperature is determined.
B.1.2 For tanks that are insulated, the tank shell temperature (TSh) is assumed to be the same as the
temperature of the product (TL) stored within the tank (that is, TSh = TL). For tanks that are not insulated, the shell temperature is a weighted average of the ambient and the product temperature based the following equation:
TSh = [(7 x TL) + TA] / 8
Where TL = liquid product temperature
TA = ambient air temperature
B.1.3 Once the shell temperature is determined, the shell temperature correction factor (CTSh) is
computed using the following equation:
CTSh = 1 + 2άΔT + ά2ΔT2
Where: ά = Linear coefficient of expansion of the tank shell material
ΔT = Tank Shell Temperature (TSh) – Tank Shell Reference Temperature (TShREF)
B.2 Application of Shell Temperature Correction
Case 1: Capacity table at tank shell reference temperature (TShREF) of 60°F, of mild steel, non-
insulated construction with a linear coefficient of expansion of 0.000062/°F.
- Volume at a given level (tank shell reference temperature [TShREF] 60°F) = 100,000 bbls.
- Ambient Temperature = 70°F.
- Product Temperature = 155°F.
- Compute capacity table volume reflecting above conditions.
Solution:
a. Calculate shell temperature (TSh) at 155°F product temperature:
TSh = [(7 x TL) + TA] / 8
TSh = [(7 x 155) + 70] / 8
TSh = 144°F (rounded to nearest 1°F)
b. Compute ΔT
ΔT = Tank Shell Temperature (TSh) – Tank Shell Reference Temperature (TShREF)
ΔT = 144 - 60
ΔT = 84
c. Compute the shell temperature correction factor (CTSh) for 144°F
CTSh = 1 + 2άΔT + ά2ΔT2
ΔT = Tank Shell Temperature (TSh) - Tank Shell Reference Temperature (TShREF) CTSh = 1 + (2 x 0.0000062 x ΔT) + (0.0000062 x 0.0000062 x ΔT x ΔT)
CTSh = 1 + (0.0000124 x 84) + (0.00000000003844 x 7056)
CTSh = 1 + 0.0010416 + .00000027123264
CTSh = 1.00104 (rounded to five decimal places)
d. Compute the correct volume:
V = Volume at TSh 60°F x CTSh FOR 144°F
V = 100,000 bbls x 1.00104
V = 100,104 bbls.
Case 2: Capacity table already corrected for a tank shell temperature of 185°F, on a mild steel non-
insulated tank [see note below].
- Volume at a given level (tank shell reference temperature [TShREF] 185°F) = 100,000 bbls.
##################
- Ambient Temperature = 70°F.
- Product Temperature = 155°F.
- Compute capacity table volume reflecting above conditions.
Solution:
a. Calculate shell temperature (TSh) at 155°F product temperature:
TSh = [(7 x TL) + TA] / 8
TSh = [(7 x 155) + 70] x 70
TSh = 144°F (rounded to nearest 1°F)
b. Compute ΔT
ΔT = Tank Shell Temperature (TSh) - Tank Shell Reference Temperature (TREF)
ΔT = 144 - 185
ΔT = -41
c. Compute the shell temperature correction factor (CTSh) for 144°F
CTSh = 1 + 2άΔT + ά2ΔT2
ΔT = Tank Shell Temperature (TSh) - Tank Shell Reference Temperature (TREF) CTSh = 1 + (2 x 0.0000062 x ΔT) + (0.0000062 x 0.0000062 x ΔT x ΔT)
CTSh = 1 + (0.0000124 x -41) + (0.00000000003844 x 1681) CTSh = 1 - 0.0005084 + .00000006461764
CTSh = 0.99949 (rounded to five decimal places)
d. Compute the correct volume:
V = Volume at TSh 185°F x CTSh FOR 144°F V = 100,000 bbls x 0.99949
V = 99,949 bbls.
Note: For tanks that specify a product operating temperature, it will be necessary to obtain the actual
Tank Shell Reference Temperature (TShREF) that was used to compute the capacity table volumes. If the tank is insulated, it can be assumed that the Tank Shell Reference Temperature (TShREF) is the same as the product operating temperature. If the tank is not insulated, the user should contact the company that generated the capacity table to determine what tank shell reference temperature (TSh REF) was used.
Table B3 - Linear Thermal Expansion Coefficients of SteelType of Steel Coefficient per °F Coefficient per °CMild Carbon 0.00000620 0.0000112304 Stainless 0.00000960 0.0000173316 Stainless 0.00000883 0.000015917-4PH Stainless 0.00000600 0.0000108Table B-1 - Correction Factors for effect of Temperature on the Tank ShellFor mild steel tanks with a linear coefficient of expansion of 0.0000062/°F, whose capacity tables werecalculated ala tank shell reference temperature (TShREF) of 60°F. For temperatures outside the range of this table use the formula in API MPMS Chapter 12, Section 1, Part 1, Subpart 9.1.3.Shdl Shdl Shdl Shdl Shdl Shdl Sh<ll Shdl Shdl Shdl Shdl Shdl Shdl Sh<ll
Temp Correction Temp Correction Temp Correction Temp Correction Temp Correction Temp Correction Temp
COF) Factor COF) Factor COF) Factor COF) Factor COF) Factor COF) Factor COF)
0.99926 45 0.99981 90 1.00037 135 1.00093 180 1.00149 225 1.00205 270
1 0.99927 46 0.99983 91 1.00038 136 1.00094 181 1.00150 226 1.00206 27
2 0.99928 47 0.99984 92 1.00040 137 1.00096 182 1.00151 227 1.00207 272
3 0.99929 48 0.99985 93 1.00041 138 1.00097 183 1.00153 228 1.00208 27
4 0.99931 49 0.99986 94 1.00042 139 1.00098 184 1.00154 229 1.00210 274
5 0.99932 50 0.99988 95 1.00043 140 1.00099 185 1.00155 230 1.00211 275
6 0.99933 51 0.99989 96 1.00045 141 1.00100 186 1.00156 231 1.00212 276
7 0.99934 52 0.99990 97 1.00046 142 1.00102 187 1.00158 232 1.00213 277
8 0.99936 53 0.99991 98 1.00047 143 1.00103 188 1.00159 233 1.00215 278
CorrectionFactor
#########
2881289###
#########
294295296297###############
38 0.99973 83 1.00029 128 1.00084 173 1.00140 218 1.00196 263 1.00252 308 1.0030839 0.99974 84 1.00030 129 1.00086 174 1.00141 219 1.00197 264 1.00253 309 1.0030940 0.99975 85 1.00031 130 1.00087 175 1.00143 220 1.00198 265 1.00254 310 1.0031041 0.99976 86 1.00032 131 1.00088 176 1.00144 221 1.00200 266 1.00256 31 1.0031142 0.99978 87 1.00033 132 1.00089 177 1.00145 222 1.00201 267 1.00257 31 1.0031343 0.99979 88 1.00035 133 1.00091 178 1.00146 223 1.00202 268 1.00258 31 1.0031444 0.99980 89 1.00036 134 1.00092 179 1.00148 224 1.00203 269 1.00259 314 1.00315
2144 0.99868 0.99969 46 1.00069 91 0.00170 136 18 0.003 22643 0.99871 2 0.99971 47 1.00071 92 1.00172 137 1.00272 182 1.00373 2242 0.99873 3 0.99973 48 1.00074 93 1.00174 138 1.00275 183 1.00375 22841 0.99875 4 0.99975 49 1.00076 94 1.00176 139 1.00277 184 1.00378 22940 0.99877 5 0.99978 50 1.00078 95 1.00179 140 1.00279 185 1.00380 230 1.0048039 0.99880 6 0.99980 51 1.00080 96 1.00181 141 1.00281 186 1.00382 231 1.0048338 0.99882 7 0.99982 52 1.00083 97 1.00183 142 1.00284 187 1.00384 232 1.0048537 0.99884 8 0.99984 53 1.00085 98 1.00185 143 1.00286 188 1.00387 233 1.0048736 0.99886 9 0.99987 54 1.00087 99 1.00188 144 1.00288 189 1.00389 234 1.0048935 0.99888 10 0.99989 55 1.00089 100 1.00190 145 1.00290 190 1.00391 235 1.0049234 0.99891 11 0.99991 56 1.00092 101 1.00192 146 1.00293 191 1.00393 236 1.0049433 0.99893 12 0.99993 57 1.00094 102 1.00194 147 1.00295 192 1.00395 23 1.0049632 0.99895 13 0.99996 58 1.00096 103 1.00197 148 1.00297 193 1.00398 238 1.0049831 0.99897 14 0.99998 59 1.00098 104 1.00199 149 1.00299 194 1.00400 239 1.0050130 0.99900 15 1.00000 60 1.00100 105 1.00201 150 1.00302 195 1.00402 240 1.0050329 0.99902 16 1.00002 61 1.00103 106 1.00203 151 1.00304 196 1.00404 241 1.0050528 0.99904 17 1.00004 62 1.00105 107 1.00205 152 1.00306 197 1.00407 242 1.0050727 0.99906 18 1.00007 63 1.00107 108 1.00208 153 1.00308 198 1.00409 243 1.00510
'999819 0.99949 641.00005 109 1.00061 154 1.00117 199 1.00172 244 1.00228
20 0.99950 65 1.00006 110 1.00062 155 1.00118 200 1.00174 245 1.00230 29021 0.99952 66 1.00007 111 1.00063 156 1.00119 201 1.00175 246 1.00231 2922 0.99953 67 1.00009 112 1.00064 157 1.00120 202 1.00176 247 1.00232 292
23 0.99954 68 1.00010 113 1.00066 158 1.00122 203 1.00177 248 1.0023324 0.99955 69 1.00011 114 1.00067 159 1.00123 204 1.00179 249 1.0023425 0.99957 70 1.00012 115 1.00068 160 1.00124 205 1.00180 250 1.0023626 0.99958 71 1.00014 116 1.00069 161 1.00125 206 1.00181 251 1.0023727 0.99959 72 1.00015 117 1.00071 162 1.00127 207 1.00182 252 1.0023829'
50 l6 l.0007 53 .00 .O '"
NOTE IFTANK IS INSULATEDUse Product Temperature as Tank Shell Temperature in This SituationTable B-2- Correction Factors for effect of Temperature on the Tank ShellFor mild steel tanks with a linear coefficient of expansion of 0.00001116fCC, whose capacity tables werecalculated ala tank shell reference temperature (TShREF) of 15°C. For temperatures outside the range of this table use the formula in API MPMS Chapter 12, Section 1, Part 1, Subpart 9.1.3.Shdl Shdl Sh<ll Shdl Shdl Shdl Shdl Shdl Shdl Shdl Shdl Sh<ll Shdl ShdlTemp Correction Temp Correction Temp Correction Temp Correction Temp Correction Temp Correction Temp
COC Factor C0C Factor oc Factor Factor Factor Factor C0C
CorrectionFactor
l.00270 1.004 721.004 741.004 761.004 78
26 0.99909 19 1.00009 64 1.00109 109 1.00210 154 1.00310 199 1.00411 244 1.0051225 0.99911 20 1.00011 65 1.00112 110 1.00212 155 1.00313 200 1.00413 245 1.0051424 0.99913 21 1.00013 66 1.00114 111 1.00214 156 1.00315 201 1.00416 246 1.0051623 0.99915 22 1.00016 67 1.00116 112 1.00217 157 1.00317 202 1.00418 24 1.0051822 0.99917 23 1.00018 68 1.00118 113 1.00219 158 1.00319 203 1.00420 248 1.0052121 0.99920 24 1.00020 69 1.00121 114 1.00221 159 1.00322 204 1.00422 249 1.0052320 0.99922 25 1.00022 70 1.00123 115 1.00223 160 1.00324 205 1.00425 250 1.0052519 0.99924 26 1.00025 71 1.00125 116 1.00226 161 1.00326 206 1.00427 251 1.0052718 0.99926 27 1.00027 72 1.00127 117 1.00228 162 1.00328 207 1.00429 252 1.0053017 0.99929 28 1.00029 73 1.00129 118 1.00230 163 1.00331 208 1.00431 253 1.0053216 0.99931 29 1.00031 74 1.00132 119 1.00232 164 1.00333 209 1.00433 254 1.0053415 0.99933 30 1.00033 75 1.00134 120 1.00234 165 1.00335 210 1.00436 255 1.0053614 0.99935 31 1.00036 76 1.00136 121 1.00237 166 1.00337 211 1.00438 256 1.0053913 0.99938 32 1.00038 77 1.00138 122 1.00239 167 1.00340 212 1.00440 257 1.0054112 0.99940 33 1.00040 78 1.00141 123 1.00241 168 1.00342 213 1.00442 258 1.0054311 0.99942 34 1.00042 79 1.00143 124 1.00243 169 1.00344 214 1.00445 259 1.0054510 0.99944 35 1.00045 80 1.00145 125 1.00246 170 1.00346 215 1.00447 260 1.00548
9 0.99946 36 1.00047 81 1.00147 126 1.00248 171 1.00348 216 1.00449 261 1.005508 0.99949 37 1.00049 82 1.00150 127 1.00250 172 1.00351 217 1.00451 262 1.005527 0.99951 38 1.00051 83 1.00152 128 1.00252 173 1.00353 218 1.00454 263 1.005546 0.99953 39 1.00054 84 1.00154 129 1.00255 174 1.00355 219 1.00456 264 1.00557
NOTE IFTANK IS INSULATEDUse Product Temperature as Tank Shell Temperature in This Situation
ANNEX CEXAMPLES OF BOTH TYPES OF FLOATING ROOF ADJUSTMENTS (NORMATIVE)
C1: Example when roof calculation is calculated into the tank capacity table:
Calculation of the secondary correction for the difference between the reference density
and the observed density when the primary roof correction is built into the capacity table using reference density.
Input Data:
Product: Crude Oil
API gravity @ 60ºF: 40.3
Temperature of liquid: 84.0ºF
Excerpt from a tank capacity table:
“A total of 4,088.2662 barrels was deducted from this table between 4 feet 00 inches and 5 feet 00 inches for floating roof displacement based on a weight of 1,215,000 pounds and a gravity of 35.0 API. Gauged quantities above 5 feet 00 inches reflect this deduction but shall be adjusted for varying API gravities at tank temperature according to the following.”
Referenced observed API gravity 35.0: no adjustment
For each 1.0 API below 35.0 API: add 24.59 barrels
For each 1.0 API above 35.0 API: subtract 24.59 barrels
Step 1: Calculate the observed API gravity for an API gravity at 60ºF of 40.3 and an
observed temperature of the liquid of 84.0ºF. This is done by working backwards using API MPMS Chapter 11.1/Adjunct to ASTM D1250/Adjunct to IP 200, Table 5A (or 5B if the tank content is a petroleum product) as shown in Table 4.
Note: Table 6 is an excerpt from using API MPMS Chapter 11.1-1980/Adjunct to
ASTM D1250-80/Adjunct to IP 200/80, Table 5A.
Note: When the API gravity @ 60 F does not fall on an exact gravity, the user must interpolate
between gravities to arrive at the correct observed gravity. For example, the API @ 60 F to be corrected to observed, is 40.3. Looking up the gravity on Table 4 indicates the gravity falls between
40.0 and 40.4 or 3/4 of the difference between the observed gravities at the top of the table. The
API of 40.3 falls between the observed gravities of 42.0 and 42.5, which have a difference of 0.5 gravity. To determine what 40.3 equates to as an observed gravity, calculate what 3/4 of 0.5 gravity. The calculation equates to 0.4 (rounded). Add this to the 42.0 and the observed gravity that equates to 40.3 @ 60 is 42.4 API.
Step 2: Calculate the difference between the observed API gravity and the referenced
observed API gravity as follows:
Referenced observed API gravity 35.0: no adjustment
For each 1.0 API below 35.0 API: add 24.59 barrels
For each 1.0 API above 35.0 API: subtract 24.59 barrels
Referenced observed API gravity: 35.0
Observed API gravity @ 84ºF: 42.4
difference: 7.4
For each 1.0 API above 35.0 API, subtract 24.95 barrels. (7.4) x (-24.59) = -181.97 barrels
42.4
75.0 38.8 39.2 39.7 40.2 40.7 41.2 41.7 42.2 42.7 43.2 43.6 75.0
75.5 38.7 39.2 39.7 40.2 40.7 41.2 41.6 42.1 42.6 43.1 43.6 75.576.0 38.7 39.2 39.7 40.1 40.6 41.1 41.6 42.1 42.6 43.1 43.6 76.076.5 38.6 39.1 39.6 40.1 40.6 41.1 41.6 42.0 42.5 43.0 43.5 76.577.0 38.6 39.1 39.6 40.1 40.5 41.0 41.5 42.0 42.6 43.0 43.5 77.0
77.5 38.6 39.0 39.5 40.0 40.5 41.0 41.5 42.0 42.4 42.9 43.4 77.5
78.0 38.5 39.0 39.5 40.0 40.5 40.9 41.4 41.9 42.4 42.9 43.4 78.078.5 38.5 39.0 39.4 39.9 40.4 40.9 41.4 41.9 42.4 42.8 43.3 78.579.0 38.4 38.9 39.4 39.9 40.4 40.9 41.3 41.8 42.3 42.8 43.3 79.079.5 38.4 38.9 39.4 39.8 40.3 40.8 41.3 41.8 42.3 42.8 43.2 79.5
80.0 38.3 38.8 39.3 39.8 40.3 40.8 41.3 41.7 42.2 42.7 43.2 80.0
80.5 38.3 38.8 39.3 39.8 40.2 40.7 41.2 41.7 42.2 42.7 43.2 80.581.0 38.3 38.8 39.2 39.7 40.2 40.7 41.2 41.7 42.1 42.6 43.1 81.081.5 38.2 38.7 39.2 39.7 40.2 40.7 41.1 41.6 42.1 42.6 43.1 81.582.0 38.2 38.7 39.2 39.6 40.1 40.6 41.1 41.6 42.1 42.5 43.0 82.0
82.5 38.1 38.6 39.1 39.6 40.1 40.6 41.0 41.5 42.0 42.5 43.0 82.5
83.0 38.1 38.6 39.1 39.6 40.0 40.5 41.0 41.5 42.0 42.5 42.9 83.083.5 38.1 38.5 39.0 39.5 40.0 40.5 41.0 41.4 41.9 42.4 42.9 83.584.0 38.0 38.5 39.0 39.5 40.0 40.4 40.9 41.4 41.9 42.4 42.8 84.084.5 38.0 38.5 39.0 39.4 39.9 40.4 40.9 41.4 41.8 42.3 42.8 84.5
85.0 37.9 38.4 38.9 39.4 39.9 40.4 40.8 41.3 41.8 42.3 42.8 85.0
85.5 37.9 38.4 38.9 39.4 39.8 40.3 40.8 41.3 41.8 42.2 42.7 85.586.0 37.9 38.3 38.8 39.3 39.8 40.3 40.7 41.2 41.7 42.2 42.7 86.086.5 37.8 38.3 38.8 39.3 39.7 40.2 40.7 41.2 41.7 42.2 42.6 86.587.0 37.8 38.3 38.7 39.2 39.7 40.2 40.7 41.1 41.6 42.1 42.6 87.0
87.5 37.7 38.2 38.7 39.2 39.7 40.1 40.6 41.1 41.6 42.1 42.5 87.5
88.0 37.7 38.2 38.7 39.1 39.6 40.1 40.6 41.1 41.5 42.0 42.5 88.088.5 37.7 38.1 38.6 39.1 39.6 40.1 40.5 41.0 41.5 42.0 42.5 88.589.0 37.6 38.1 38.6 39.1 39.5 40.0 40.5 41.0 41.5 41.9 42.4 89.089.5 37.6 38.1 38.5 39.0 39.5 40.0 40.5 40.9 41.4 41.9 42.4 89.5
90.0 37.5 38.0 38.5 39.0 39.5 39.9 40.4 40.9 41.4 41.8 42.3 90.0
Floating roof adjustment = -181.97 barrelsTable 6
Generalized Crude Oils API Correction to 60ºF
API Gravity at Observed Temperature
Temp. ºF 40.0 40.5 41.0 41.5 42.0 42.5 43.0 43.5 44.0 44.5 45.0 Temp ºF
Corresponding API Gravity at 60ºF
*Denotes Extrapolated Value API Gravity = 40.0 to 45.0
C2: Example when roof adjustment is not calculated in the tank capacity table
The roof deduction is calculated by dividing the weight of the floating roof by the weight per unit volume at
standard temperature multiplied by the CTPL to bring this to observed conditions.
Roof correction = Weight of roof
Density in air x CTPL
Note: The density units must be consistent to both the CTPL and the units of the roof weight, in addition
to being a density in air. For example, if the density is lbs/gal @ 60ºF, then the roof weight must be in pounds and the CTPL applicable to a standard temperature of 60ºF. Additionally, this particular example will yield a roof correction in gallons. If the table units are in barrels, it will be necessary to divide the result by 42.
Calculate a floating roof adjustment when no corrections have been made to the tank
capacity table for the roof. (See note.)
Gross observed volume corrected for CTSh = 242,362.15 barrels
Product: Crude Oil
API gravity @ 60ºF: 40.3
Temperature of liquid: 84.0ºF CTPL (Table 6A): 0.9879
Weight of floating roof: 1,215,000 pounds
Weight per unit volume of liquid: 6.858 pounds/gallons (See note.)
FRC = weight of roof
density in air x CTPL
FRC = 1,215,000
6.858 x 0.9879
FRC = 179,335.26 gallons = -4,269.89 barrels
Gross observed volume corrected for FRC = 238,092.26 barrelsNOTE: The FRC correction is always negative and must be subtracted from the tank volume.
Suggested revisions to this publication are invited and should be submitted to the Measurement Coordinator, Exploration and Production Department, American Petroleum Institute, 1220 L Street, N.W., Washington, D.C. 20005.
Table B-1 - Correction Factors for Effect of Temperature on the Tank Shell – Reference Temp 60ºF Table B-2 - Correction Factors for Effect of Temperature on the Tank Shell – Reference Temp 15ºC Table B-3 - Linear Thermal Expansion Coefficients of Steel
B-2 - Correction Factors for Effect of Temperature on the Tank Shell – Reference Temp 15ºC B-3 - Linear Thermal Expansion Coefficients of Steel
of crude oil, petroleum products, and petrochemicals when contained in tanks. This publication will also address calculation sequences, rounding, and significant digits, with the aim that different operators can produce identical results from the same observed data.
quantities, at atmospheric conditions, in upright, cylindrical tanks and marine tank vessels. The standard defines terms employed in the calculation of static petroleum quantities.
The standard also specifies equations that allow the values of some correction factors to be computed. Fundamental to this process is the understanding that in order for different parties to be able to reconcile volumes, they must start with the same basic information (tank capacity table, levels, temperatures, and
This standard does not address the calculation of clingage, non-liquid material, small quantities (such as onboard quantities, quantities remaining on board, and Wedge Formula, where material is not touching all bulkheads on marine vessels), and vapor space calculations.
The definition of those terms relative to this document can be found in other API or associated documents, as follows:
The designation of corrections and correction factors by abbreviations rather than words is recommended to abbreviate the expression, facilitate algebraic manipulation, and reduce confusion. While a combination of upper case, lower case, subscripted, and superscripted notation is used, upper case notation may be used as appropriate. Additional letters may be added to symbolic notations for clarity and specificity.
Corrects a volume at an observed temperature & pressure to an equivalent volume at base temperature and pressure and is equal to CTL x CPL. For the purpose of this standard, base pressure is equivalent to atmospheric pressure and the CPL factor is considered to be 1.00000; therefore, under atmospheric conditions, the CTPL and CTL will be the same value. (CTPL and CTL are referred to as VCF in some
Mass per unit volume; i.e. the mass of a substance divided by its volume. When reporting density, the unit used together with temperature shall be explicitly stated; for example, kilograms per cubic meter at 15ºC
A secondary correction or adjustment for any difference between the reference density and the observed density at tank temperature, when a correction for the roof has been calculated into the tank capacity table using a reference density.
The correction made to offset the effect of the displacement of the floating roof, when no correction has been built into the tank capacity table.
The water present in a container that is not suspended in the liquid hydrocarbon. A free water quantity deduction may include bottom sediments.
The total volume of all petroleum liquids and sediment and water, excluding free water, at observed temperature and pressure.
The total volume of all petroleum liquids and sediment and water, excluding free water, corrected by the appropriate volume correction factor (CTPL) for the observed temperature and API gravity, relative density, or density to a standard temperature such as 60ºF or 15ºC.
The total volume of all petroleum liquids, excluding sediment and water and free water, corrected by the appropriate volume correction factor (CTPL) for the observed temperature and API gravity, relative density, or density to a standard temperature such as 60ºF or 15ºC.
The total volume of all petroleum liquids and sediment and water corrected by the appropriate volume correction factor (CTPL) for the observed temperature and API gravity, relative density, or density to a standard temperature such as 60ºF or 15ºC and all free water measured at observed temperature (gross standard volume plus free water).
Total measurement volume of all petroleum liquids, sediment and water, free water, and bottom sediments at observed temperature. For the purposes of this standard, TOV is the volume taken from the tank capacity table prior to any corrections, such as those for floating roof and the temperature of the tank shell.
This is the same as CTL and under atmospheric conditions is also the same as CTPL, making these three symbols interchangeable; however, only CTPL and CTL are used in equations in this standard.
is organized into Chapters covering general measurement areas and several of these Standards are interrelated, in particular Chapters 11 and 12. If there is uncertainty amongst users as to which takes precedence the following criteria should be applied.
is the primary standard for the determination of the temperature (CTL), pressure (CPL), and combined temperature and pressure (CTPL) correction factors for crude oil, refined products, and lubricating oils, either by presentation of specific implementation procedures or by reference to other publications.
discrimination levels (rounding) required for each input variable and correction factor in a specific volume calculation procedure, and the sequence and manner in which to apply the appropriate parameters (RHO b, APIb, RDb, CTL, Fp, CPL, and CTPL).
base” conditions. The “standard” or “base” condition is a defined combination of temperature and pressure at which liquid volumes are expressed for purposes of custody transfer, stock accounting, etc. The terms
is called the "compressibility coefficient" or "scaled compressibility factor (units of 1/psi)". For additional information on these terms, refer to API MPMS Chapter 11.1.
by a National Metrology Institute (NMI) such as the National Institute of Standards and Technology (NIST) in the United States. From this level downwards, any uncertainty in a higher level must be reflected in all lower levels as a bias or systematic error. Whether such bias will be positive or negative is unknown as uncertainty carries either possibility.
To expect equal or less uncertainty in a lower level of the hierarchy than exists in a higher level is unrealistic. The only way to decrease the random component of uncertainty in a given measurement system is to increase the number of determinations and then find their mean value. The number of digits in intermediate calculations of a value can be larger in the upper levels of the hierarchy than in the lower levels, but the temptation to move towards imaginary significance (more decimal places) must be tempered or resisted by a wholesome respect for realism.
data itself. For example, if a vessel’s capacity tables are calibrated to the nearest whole barrel, than all subsequent barrel values should be recorded accordingly. However, in those cases where there are no other limiting factors, the operator should be guided as follows by Table 1.
11.1-2004 have been invoked. For those invoking the “Grandfather Clause”, the following note, from API MPMS Chapter 11.1-1980, which was applicable to the CTL, is reproduced here for ease of reference. “The standard for determining CTL factors is the computer subroutine implementation procedures of API MPMS Chapter 11.1, Volume X. When fully implemented, this generates a CTL factor of five significant digits. That is, five decimal digits at temperatures above standard temperature (60ºF and 15ºC) and four decimal digits at temperatures below standard temperature. Use of the printed table limits the user to
four decimal digits above and below standard temperature in addition to limiting table entry discrimination to 0.5ºF, 0.25ºC, 0.5 API, and 2.0 kg/m3. In the event of dispute, the computer-generated CTL should take preference.”
one step to the number of figures that are to be recorded and shall not be rounded in two or more steps of successive rounding. In absolute terms, when the figure to the right of last place to be retained is 5 or greater, the figure in the last place to be retained should be increased by 1. If the figure to the right of the last place to be retained is less than 5, the figure in the last place retained should be unchanged.
compliance with the calculation procedures of this standard. The data in Table 1 should not be used to construe or imply accuracy requirements or the capabilities (discrimination) of instrumentation used to furnish the measurements.
Where used to verify conformance to calculation procedures, the accounting hardware that displays or prints results from calculations shall have at least 32 bit binary word length or be capable of enough digits to preserve the resolution and display the maximum quantity required for the application – typically, this is
10 digits or better. In certain situations, such as with on-line real time calculations that are required by process measurement instrumentation, the available equipment may not have this capacity. In such cases, rounding and discrimination levels should be as close to the standard as the computing hardware will allow.
document does not address how these data are obtained. That information is found in the referenced publications listed in Section 2, and it is assumed, for the purpose of this document, that all such data have been obtained in accordance with these referenced publications. It should be understood that the observed data must be gathered concurrently. In other words, the level gauge, water cut, temperature, and so forth should all be taken at the same time for inclusion on the same measurement ticket or ullage report.
Observed reference gauge heighta Observed reference gauge heighta Innage or ullage or liquid level Innage or ullage of liquid level Innage or ullage of free water level Innage or ullage of free water level
Average liquid temperature ºF or ºC Average liquid temperature ºF or ºC Observed density @ sample temperature Observed density @ sample temperature Percentage of sediment and water Percentage of sediment and water Ambient air temperature Forward draft reading
These data points do not have any direct impact on the calculation process. However, they can impact the calculation process indirectly and are usually recorded at this time.
Floating roof adjustment or correction Density @ standard temperature Tank shell temperature correction Trim correction and list correction Total observed volume Total observed volume
Sediment and water (volume or factor) Sediment and water (volume or factor) Net standard volume Net standard volume
; then, apply the floating roof adjustment (FRA), where applicable.
capacity tables based on a specific tank shell temperature. If the observed tank shell temperature differs from the capacity table tank shell temperature, the volumes extracted from that table will need to be corrected accordingly.
Storage tanks differ from test measures in size and wall thickness. Differences also occur because the tanks cannot readily be sheltered from the elements. Therefore, ambient temperatures as well as product temperatures must be considered when calculating an appropriate correction for the effect of temperature on the shell of the tank. The correction factor for the effect of temperature on the shell of the tank is called CTSh and may be calculated by the following:
) is usually stated on the capacity table. If this is not the case, contact the company that generated the table. Some capacity tables make reference to an operating product temperature; this should not be confused with the Tank Shell Reference Temperature (TSh REF), which is a tank shell temperature.
gauging tanks. Take at least one temperature reading in a shaded area. If more than one temperature is taken, average the readings.
shell correction factors during custody transfer shall have their accuracy of plus or minus two degrees Fahrenheit verified every three months.
considered separately. The volumes reflected on tank tables are derived from area multiplied by incremental height. Therefore, K- factors for correction of areas have the same ratio as volume corrections and may be applied directly to tank table volumes. For an example calculation see Annex B.
that are at standard conditions and are unrelated to the corrections designed to account for volume expansion and contraction of the product itself. Depending upon certain requirements, this shell temperature correction factor may be built into the capacity table for a specific operating temperature.
determine the floating roof adjustment or correction is the same for both types of roofs. The determination of the correction, however, can be addressed in one of two ways:
the roof; therefore a volume, equivalent to the entire weight of the roof, must be calculated and applied as a correction. This correction is always negative and is calculated by dividing the weight of the floating roof by observed density at tank temperature.
amount of trim and/or list correction will need to be applied to the TOV quantity to arrive at a trim and/or list corrected TOV.
c. The observed ullage or innage and the vessel’s trim. Some capacity tables show varying TOV values for the same gauge under differing conditions of trim.
Subtract the forward draft reading from the after draft reading. If the trim is positive (that is, the after draft reading is larger), the vessel is said to be “trimmed by the stern.” If the trim is negative (that is, the forward draft reading is larger), the vessel is said to be “trimmed by the head.” Note the following:
b. Trim corrections can be either positive or negative. The trim correction table will state how this correction is to be applied.
vessel not being perpendicular to the horizontal. A vessel’s list is usually read from its inclinometer. However, if such an instrument is not available or there is doubt as to its accuracy, then the list can be calculated from the port and starboard amidships draft readings. Refer to Figure 1 for this calculation. Note the following:
b. List corrections can be either positive or negative. The list correction table will state how this correction is to be applied.
corrections are only applicable when the other condition does not exist. For information on the calculation procedure for combined trim and list corrections, refer to API MPMS Chapter 2.8A, Section 10.4.
ullage. As with any liquid in a marine vessel’s tank, FW is subject to the effects of trim and list, and the previously referenced trim and list corrections are applicable to FW, provided that the FW is touching all bulkheads of the tank. If the FW does not touch all tank bulkheads, a wedge condition exists. The
formula for calculating whether or not a wedge condition exists, the application of wedge tables/formulae, and the calculation of the wedge formula can be found in API MPMS Chapter 17.4.
rises or decrease as the temperature falls. The volume change is proportional to the thermal coefficient of expansion of the liquid, which varies with density (API gravity) and temperature. The correction factor for the effect of the temperature and pressure on a volume of liquid is called CTPL, CTL or VCF. The function of this correction factor is to adjust the volume of liquid at observed temperature to its volume at a standard temperature. The most common standard temperatures are 60ºF, 15ºC, and 20ºC (68ºF).
or the Adjunct to IP 200. These computer programs or tables are entered with the observed average temperature and API gravity at 60ºF, a density at 15ºC, a relative density at 60ºF/60ºF, or a coefficient of thermal expansion. To determine which table is applicable, refer to Table 4.
ASTM D4311 Asphalt to 60ºF, Table 1 ºF API gravity @ 60ºF, Table A or B ASTM D4311 Asphalt to 15ºC, Table 2 ºC Density @ 15ºC, Table A or B
developed by the manufacturer. These are usually in the form of product specific tables of CTL (VCF), showing the factor at observed temperatures, which must be applied to obtain the volume at standard temperature; or, a volume correction factor, per degree difference in observed temperature. While these individual tables can have their own parameters and table entry requirements, their application is the same.
value from 100, thus determining the NSV as a percentage of the GSV, divide this by 100, and multiply the GSV by it.
values are known. However, it can be calculated on a grade or parcel basis if the S&W was analyzed on an appropriate representative sample.
that fluid. The quantity of sediment and water is determined by laboratory analysis of a representative sample and is expressed as a percentage, usually volume percent. For information on how sediment and water analysis is performed, refer to API MPMS Chapter 10 or its ASTM equivalents.
referred to in this document, mass will refer to weight in vacuum (vacuo) and weight will refer to weight in air. If the same material is measured in a vacuum and then in air, the measured quantity in air will be lighter than that of the measured quantity in vacuum by an amount equal to the volume of air displaced by the material being measured. In other words the weight measured in air is affected by the “buoyancy” of the air surrounding the object.
temperature by applying a CTPL or CTL (VCF) after which the weight/mass is obtained by multiplying the standard volume with the density at the same standard temperature. If mass is required use the density in vacuum. If weight is required use the density in air
a thermal expansion coefficient per degree, then, multiplying it by the volume at observed temperature to obtain mass or weight. If mass is required use the density in vacuum. If weight is required use the density in air
density materials will displace less air than low density materials; therefore, the difference between weight in air and weight in vacuum varies with density and will have the greatest impact on low density materials. While this difference is not large, it is measurable and typically impacts the third and fourth decimal place of the density, by an amount shown in the table below.
, therefore, the most common correction is 1.1; however, densities above 996.6 kg/m3 are not uncommon, especially in the chemical industry. When adjusting a density in vacuum to its corresponding density in air, the correction is subtracted. When adjusting a density in air to its corresponding density in vacuum, the
Chapter 11.5.3 specifies a formula for making this conversion, which is reproduced below.
liquid head rather than liquid level. The calculation algorithms used by these methods may include corrections for the effect of temperature and pressure on the liquid (10.2), for the effect of liquid density on the floating roof (9.1.4), or the effect of temperature on the shell of the tank (9.1.3). In such cases,
necessary to obtain all the observed information that will be needed in order to calculate a net volume. It is the user’s responsibility to obtain that information from the standards referenced earlier. While there are some precautionary notes in the text of this document, it is assumed that the user will come to this standard with all the observed information necessary to begin to calculate net volumes. The information needed is liquid level, FW level, product temperature, ambient temperature, density, and S&W percentage. It will also be necessary to have the capacity table and applicable correction factor tables or
b. Subtract any gauged FW volumes. The FW volume is obtained by entering the capacity table with the gauged FW level.
e. Correct the GOV to standard temperature. This is done by multiplying the GOV by the CTPL to arrive at the GSV.
f. Adjust for any measured amount of S&W. This is done by multiplying GSV by the CSW. g. If net standard weight [NSW] is required, multiply the result from Item f. the density in air
necessary to report any intermediate values, the figure should be rounded as required in Section 5; however, the rounded figure is not to be inserted into the calculation sequence. See Annex A for examples of shore tank and marine vessel tank calculations.
b. Subtract any gauged FW volumes. The FW volume is obtained by entering the capacity table with the gauged FW level.
e. Correct the GOV to mass or weight. This is done by multiplying the GOV by the density in air at observed temperature to arrive at the weight or density in vacuum at observed temperature to arrive at the mass.
standard weight [NSW] is required. Should this be required, the density at standard temperature should be applied to the mass or weight, as appropriate, to arrive at gross standard volume [GSV].
necessary to report any intermediate values, the figure should be rounded as required in Section 6; however, the rounded figure is not to be inserted into the calculation sequence. See Annex A for examples of shore tank and marine vessel tank calculations.
contents are not in motion. The calculation of transferred volumes for custody transfer typically involves performing the same calculation before and after a transfer and determining the difference. If multiple tanks are involved this process is repeated for each tank and the sum of the quantity transferred from each tank is the total quantity transferred. However, when multiple tanks are involved, there are numerous variations on how the total transferred quantity can be calculated. In many cases the GSV is
and mass or weight are made collectively to this quantity. Alternatively, the individual opening and closing readings can be calculated to NSV, mass or weight and totalized accordingly. The differences resulting from these variations are usually very small and it is not the intent of this standard to specify a single method for this. Examples A1 and A2 in Annex A outline two of the more commonly used methods; however, these should not be construed as the only acceptable methods. The method used for custody transfer should be that as agreed to by the commercial parties to the transaction.
necessary to establish unique calculation procedures for lease tanks. This procedure is applicable to lease tanks of 5,000 barrels (795 m3) or less and assumes that the clearance sample has verified merchantable oil at least 4 inches below the tank outlet. The CTSh is not significant to these situations
include these quantities in custody transfer calculations as the volumes lost are not available again, except through refining. Any adjustments made as a result of volumetric shrinkage are strictly upon agreement of the commercial parties involved.
(crude oil systems, for example) will need to accumulate base data differently than for transfers that do not include the use of an automatic sampler. While the volume calculation procedures for movements into a tank involving an automatic sampling system will be the same, the method of collecting the base information will be different. (Movements out of a tank are less affected as there is less blending of densities taking place). However, it may be necessary to report the density, as determined from the automatic sampling system, somewhere on the measurement ticket or report. Regardless, it will still be necessary to sample the tank before and after a receipt because of the following:
b. After the transfer, the incoming product has been blended with whatever was in the tank. In order for the CTPL and FRA to be correct, they will have to be based on the density of the product as found in the tank.
c. The tank’s FW level must be left the same on the closing report as on the opening report. All deducted water volumes should come from the sampler and be accounted for in the form of correction for S&W (CSW).
d. S&W are usually only deducted on crude oil cargoes. Petroleum products are not usually corrected for S&W unless required as a commercial condition or other specific requirement; therefore net standard volume = gross standard volume.
conversions and this standard does not attempt to define any specific routines for converting from one unit to another; however, the user should be guided by the following:
Conversion units that are “exact by definition” are to be considered primary and shall be used whenever possible
The use of multiple conversion factors should be avoided if possible. If this cannot be avoided the process that uses the least number of conversion factors shall be used.
Quantity from the tank capacity table using the liquid level gauge to enter the table. For this example, it is assumed that any correction to the gauge, due to expansion or contraction of the tape itself, has already been made. This issue is not addressed in this standard. The user should refer to the tape manufacturer’s instructions for specific details.
As displayed on a 12-digit calculator. Actual discrimination is determined by the calculating capacity of the calculation hardware.
Sediment and water percent 0.17% Forward draft 36’ 06” After draft 38’ 00” Trim (by the stern) 1’ 06” List (vessel upright) No list
Not all trim (or list) corrections are volumetric. Many are linear adjustments that are made to the observed ullage. In this case, the adjustment would be made before entering the vessel’s capacity table and a volumetric adjustment would not be necessary. If a volumetric list correction was applicable, it would be applied at this point in the calculation.
As displayed on a 12-digit calculator. Actual discrimination is determined by the calculating capacity of the calculation hardware.
The volumetric value for sediment and water is determined by subtracting the net standard volume from the gross standard volume.
Free water gauge 10 mm Density at 15ºC kg/l (air) 0.8643 kg/l Liquid temperature ºC 22.3ºC Ambient temperature ºC 18.0ºC
that any correction to the gauge, due to expansion or contraction of the tape itself, has already been made. This issue is not addressed in this standard. The user should refer to the tape manufacturer’s instructions for specific details.
As displayed on a 12-digit calculator. Actual discrimination is determined by the calculating capacity of the calculation hardware.
(From Table 5 in Section 12.3) Density at 15ºC kg/l (vacuum) 0.7440
Quantity from the tank capacity table using the liquid level gauge to enter the table. For this example, it is assumed that any correction to the gauge, due to expansion or contraction of the tape itself, has already been made. This issue is not addressed in this standard. The user should refer to the tape manufacturer’s instructions for specific details.
Chapter 11.1/Adjunct to ASTM D1250/Adjunct to IP 200 “C” Tables; however, this example is applicable to any CTPL/VCF that derives form these “C” tables.
As displayed on a 12-digit calculator. Actual discrimination is determined by the calculating capacity of the calculation hardware.
Liquid level gauge 5810 mm Free water gauge None Found Density at 15ºC (air) kg/l 0.8831 kg/l (air) Thermal Density Coefficient / ºC 0.00100 kg/l per ºC Liquid temperature ºC 22.5ºC
is assumed that any correction to the gauge, due to expansion or contraction of the tape itself, has already been made. This issue is
temperature of 60°F. For tanks with capacity tables calculated at a reference tank shell temperature other than 60°F, the table can still be used. However, it is necessary to subtract the reference temperature from the shell temperature and then add 60 to arrive at the temperature used to enter the table. It is important to pay attention to the algebraic signs (positive or negative) when performing this calculation.
Such expansion or contraction in tank volume may be computed once the tank shell temperature is determined.
). For tanks that are not insulated, the shell temperature is a weighted average of the ambient and the product temperature based the following equation:
) CTSh = 1 + (2 x 0.0000062 x ΔT) + (0.0000062 x 0.0000062 x ΔT x ΔT)
) CTSh = 1 + (2 x 0.0000062 x ΔT) + (0.0000062 x 0.0000062 x ΔT x ΔT)
) that was used to compute the capacity table volumes. If the tank is insulated, it can be assumed that the Tank Shell Reference Temperature (TShREF) is the same as the product operating temperature. If the tank is not insulated, the user should contact the company that generated the capacity table to determine what tank shell reference temperature (TSh REF) was used.
calculated ala tank shell reference temperature (TShREF) of 60°F. For temperatures outside the range of this table use the formula in API MPMS Chapter 12, Section 1, Part 1, Subpart 9.1.3.
COF) Factor COF)
calculated ala tank shell reference temperature (TShREF) of 15°C. For temperatures outside the range of this table use the formula in API MPMS Chapter 12, Section 1, Part 1, Subpart 9.1.3.
and the observed density when the primary roof correction is built into the capacity table using reference density.
A total of 4,088.2662 barrels was deducted from this table between 4 feet 00 inches and 5 feet 00 inches for floating roof displacement based on a weight of 1,215,000 pounds and a gravity of 35.0 API. Gauged quantities above 5 feet 00 inches reflect this deduction but shall be adjusted for varying API gravities at tank temperature according to the following.”
Chapter 11.1/Adjunct to ASTM D1250/Adjunct to IP 200, Table 5A (or 5B if the tank content is a petroleum product) as shown in Table 4.
between gravities to arrive at the correct observed gravity. For example, the API @ 60 F to be corrected to observed, is 40.3. Looking up the gravity on Table 4 indicates the gravity falls between
API of 40.3 falls between the observed gravities of 42.0 and 42.5, which have a difference of 0.5 gravity. To determine what 40.3 equates to as an observed gravity, calculate what 3/4 of 0.5 gravity. The calculation equates to 0.4 (rounded). Add this to the 42.0 and the observed gravity that equates to 40.3 @ 60 is 42.4 API.
to being a density in air. For example, if the density is lbs/gal @ 60ºF, then the roof weight must be in pounds and the CTPL applicable to a standard temperature of 60ºF. Additionally, this particular example will yield a roof correction in gallons. If the table units are in barrels, it will be necessary to divide the result by 42.
Suggested revisions to this publication are invited and should be submitted to the Measurement Coordinator, Exploration and Production Department, American Petroleum Institute, 1220 L Street, N.W., Washington, D.C. 20005.
Table B-1 - Correction Factors for Effect of Temperature on the Tank Shell – Reference Temp 60ºF Table B-2 - Correction Factors for Effect of Temperature on the Tank Shell – Reference Temp 15ºC Table B-3 - Linear Thermal Expansion Coefficients of Steel
of crude oil, petroleum products, and petrochemicals when contained in tanks. This publication will also address calculation sequences, rounding, and significant digits, with the aim that different operators can produce identical results from the same observed data.
The standard also specifies equations that allow the values of some correction factors to be computed. Fundamental to this process is the understanding that in order for different parties to be able to reconcile volumes, they must start with the same basic information (tank capacity table, levels, temperatures, and
This standard does not address the calculation of clingage, non-liquid material, small quantities (such as onboard quantities, quantities remaining on board, and Wedge Formula, where material is not touching all bulkheads on marine vessels), and vapor space calculations.
The designation of corrections and correction factors by abbreviations rather than words is recommended to abbreviate the expression, facilitate algebraic manipulation, and reduce confusion. While a combination of upper case, lower case, subscripted, and superscripted notation is used, upper case notation may be used as appropriate. Additional letters may be added to symbolic notations for clarity and specificity.
Corrects a volume at an observed temperature & pressure to an equivalent volume at base temperature and pressure and is equal to CTL x CPL. For the purpose of this standard, base pressure is equivalent to atmospheric pressure and the CPL factor is considered to be 1.00000; therefore, under atmospheric conditions, the CTPL and CTL will be the same value. (CTPL and CTL are referred to as VCF in some
A secondary correction or adjustment for any difference between the reference density and the observed density at tank temperature, when a correction for the roof has been calculated into the tank capacity table using a reference density.
The total volume of all petroleum liquids and sediment and water, excluding free water, corrected by the appropriate volume correction factor (CTPL) for the observed temperature and API gravity, relative density, or density to a standard temperature such as 60ºF or 15ºC.
The total volume of all petroleum liquids, excluding sediment and water and free water, corrected by the appropriate volume correction factor (CTPL) for the observed temperature and API gravity, relative density, or density to a standard temperature such as 60ºF or 15ºC.
The total volume of all petroleum liquids and sediment and water corrected by the appropriate volume correction factor (CTPL) for the observed temperature and API gravity, relative density, or density to a standard temperature such as 60ºF or 15ºC and all free water measured at observed temperature (gross standard volume plus free water).
Total measurement volume of all petroleum liquids, sediment and water, free water, and bottom sediments at observed temperature. For the purposes of this standard, TOV is the volume taken from the tank capacity table prior to any corrections, such as those for floating roof and the temperature of the tank shell.
is organized into Chapters covering general measurement areas and several of these Standards are interrelated, in particular Chapters 11 and 12. If there is uncertainty amongst users as to which takes precedence the following criteria should be applied.
is the primary standard for the determination of the temperature (CTL), pressure (CPL), and combined temperature and pressure (CTPL) correction factors for crude oil, refined products, and lubricating oils, either by presentation of specific implementation procedures or by reference to other publications.
discrimination levels (rounding) required for each input variable and correction factor in a specific volume calculation procedure, and the sequence and manner in which to apply the appropriate parameters (RHO b, APIb, RDb, CTL, Fp, CPL, and CTPL).
by a National Metrology Institute (NMI) such as the National Institute of Standards and Technology (NIST) in the United States. From this level downwards, any uncertainty in a higher level must be reflected in all lower levels as a bias or systematic error. Whether such bias will be positive or negative is unknown as uncertainty carries either possibility.
To expect equal or less uncertainty in a lower level of the hierarchy than exists in a higher level is unrealistic. The only way to decrease the random component of uncertainty in a given measurement system is to increase the number of determinations and then find their mean value. The number of digits in intermediate calculations of a value can be larger in the upper levels of the hierarchy than in the lower levels, but the temptation to move towards imaginary significance (more decimal places) must be tempered or resisted by a wholesome respect for realism.
data itself. For example, if a vessel’s capacity tables are calibrated to the nearest whole barrel, than all subsequent barrel values should be recorded accordingly. However, in those cases where there are no other limiting factors, the operator should be guided as follows by Table 1.
“The standard for determining CTL factors is the computer subroutine implementation procedures of API MPMS Chapter 11.1, Volume X. When fully implemented, this generates a CTL factor of five significant digits. That is, five decimal digits at temperatures above standard temperature (60ºF and 15ºC) and four decimal digits at temperatures below standard temperature. Use of the printed table limits the user to
. In the event of dispute, the computer-generated CTL should take preference.”
one step to the number of figures that are to be recorded and shall not be rounded in two or more steps of successive rounding. In absolute terms, when the figure to the right of last place to be retained is 5 or greater, the figure in the last place to be retained should be increased by 1. If the figure to the right of the last place to be retained is less than 5, the figure in the last place retained should be unchanged.
compliance with the calculation procedures of this standard. The data in Table 1 should not be used to construe or imply accuracy requirements or the capabilities (discrimination) of instrumentation used to furnish the measurements.
Where used to verify conformance to calculation procedures, the accounting hardware that displays or prints results from calculations shall have at least 32 bit binary word length or be capable of enough digits to preserve the resolution and display the maximum quantity required for the application – typically, this is
10 digits or better. In certain situations, such as with on-line real time calculations that are required by process measurement instrumentation, the available equipment may not have this capacity. In such cases, rounding and discrimination levels should be as close to the standard as the computing hardware will allow.
document does not address how these data are obtained. That information is found in the referenced publications listed in Section 2, and it is assumed, for the purpose of this document, that all such data have been obtained in accordance with these referenced publications. It should be understood that the observed data must be gathered concurrently. In other words, the level gauge, water cut, temperature, and so forth should all be taken at the same time for inclusion on the same measurement ticket or ullage report.
Innage or ullage or liquid level Innage or ullage of liquid level Innage or ullage of free water level Innage or ullage of free water level
Average liquid temperature ºF or ºC Average liquid temperature ºF or ºC Observed density @ sample temperature Observed density @ sample temperature Percentage of sediment and water Percentage of sediment and water Ambient air temperature Forward draft reading
Floating roof adjustment or correction Density @ standard temperature Tank shell temperature correction Trim correction and list correction Total observed volume Total observed volume
capacity tables based on a specific tank shell temperature. If the observed tank shell temperature differs from the capacity table tank shell temperature, the volumes extracted from that table will need to be corrected accordingly.
Storage tanks differ from test measures in size and wall thickness. Differences also occur because the tanks cannot readily be sheltered from the elements. Therefore, ambient temperatures as well as product temperatures must be considered when calculating an appropriate correction for the effect of temperature on the shell of the tank. The correction factor for the effect of temperature on the shell of the tank is called CTSh and may be calculated by the following:
) is usually stated on the capacity table. If this is not the case, contact the company that generated the table. Some capacity tables make reference to an operating product temperature; this should not be confused with the Tank Shell Reference Temperature (TSh REF), which is a tank shell temperature.
considered separately. The volumes reflected on tank tables are derived from area multiplied by incremental height. Therefore, K- factors for correction of areas have the same ratio as volume corrections and may be applied directly to tank table volumes. For an example calculation see Annex B.
that are at standard conditions and are unrelated to the corrections designed to account for volume expansion and contraction of the product itself. Depending upon certain requirements, this shell temperature correction factor may be built into the capacity table for a specific operating temperature.
the roof; therefore a volume, equivalent to the entire weight of the roof, must be calculated and applied as a correction. This correction is always negative and is calculated by dividing the weight of the floating roof by observed density at tank temperature.
Subtract the forward draft reading from the after draft reading. If the trim is positive (that is, the after draft reading is larger), the vessel is said to be “trimmed by the stern.” If the trim is negative (that is, the forward draft reading is larger), the vessel is said to be “trimmed by the head.” Note the following:
vessel not being perpendicular to the horizontal. A vessel’s list is usually read from its inclinometer. However, if such an instrument is not available or there is doubt as to its accuracy, then the list can be calculated from the port and starboard amidships draft readings. Refer to Figure 1 for this calculation. Note the following:
ullage. As with any liquid in a marine vessel’s tank, FW is subject to the effects of trim and list, and the previously referenced trim and list corrections are applicable to FW, provided that the FW is touching all bulkheads of the tank. If the FW does not touch all tank bulkheads, a wedge condition exists. The
rises or decrease as the temperature falls. The volume change is proportional to the thermal coefficient of expansion of the liquid, which varies with density (API gravity) and temperature. The correction factor for the effect of the temperature and pressure on a volume of liquid is called CTPL, CTL or VCF. The function of this correction factor is to adjust the volume of liquid at observed temperature to its volume at a standard temperature. The most common standard temperatures are 60ºF, 15ºC, and 20ºC (68ºF).
or the Adjunct to IP 200. These computer programs or tables are entered with the observed average temperature and API gravity at 60ºF, a density at 15ºC, a relative density at 60ºF/60ºF, or a coefficient of thermal expansion. To determine which table is applicable, refer to Table 4.
developed by the manufacturer. These are usually in the form of product specific tables of CTL (VCF), showing the factor at observed temperatures, which must be applied to obtain the volume at standard temperature; or, a volume correction factor, per degree difference in observed temperature. While these individual tables can have their own parameters and table entry requirements, their application is the same.
that fluid. The quantity of sediment and water is determined by laboratory analysis of a representative sample and is expressed as a percentage, usually volume percent. For information on how sediment and water analysis is performed, refer to API MPMS Chapter 10 or its ASTM equivalents.
referred to in this document, mass will refer to weight in vacuum (vacuo) and weight will refer to weight in air. If the same material is measured in a vacuum and then in air, the measured quantity in air will be lighter than that of the measured quantity in vacuum by an amount equal to the volume of air displaced by the material being measured. In other words the weight measured in air is affected by the “buoyancy” of the air surrounding the object.
temperature by applying a CTPL or CTL (VCF) after which the weight/mass is obtained by multiplying the standard volume with the density at the same standard temperature. If mass is required use the density in vacuum. If weight is required use the density in air
density materials will displace less air than low density materials; therefore, the difference between weight in air and weight in vacuum varies with density and will have the greatest impact on low density materials. While this difference is not large, it is measurable and typically impacts the third and fourth decimal place of the density, by an amount shown in the table below.
are not uncommon, especially in the chemical industry. When adjusting a density in vacuum to its corresponding density in air, the correction is subtracted. When adjusting a density in air to its corresponding density in vacuum, the
liquid head rather than liquid level. The calculation algorithms used by these methods may include corrections for the effect of temperature and pressure on the liquid (10.2), for the effect of liquid density on the floating roof (9.1.4), or the effect of temperature on the shell of the tank (9.1.3). In such cases,
necessary to obtain all the observed information that will be needed in order to calculate a net volume. It is the user’s responsibility to obtain that information from the standards referenced earlier. While there are some precautionary notes in the text of this document, it is assumed that the user will come to this standard with all the observed information necessary to begin to calculate net volumes. The information needed is liquid level, FW level, product temperature, ambient temperature, density, and S&W percentage. It will also be necessary to have the capacity table and applicable correction factor tables or
necessary to report any intermediate values, the figure should be rounded as required in Section 5; however, the rounded figure is not to be inserted into the calculation sequence. See Annex A for examples of shore tank and marine vessel tank calculations.
necessary to report any intermediate values, the figure should be rounded as required in Section 6; however, the rounded figure is not to be inserted into the calculation sequence. See Annex A for examples of shore tank and marine vessel tank calculations.
contents are not in motion. The calculation of transferred volumes for custody transfer typically involves performing the same calculation before and after a transfer and determining the difference. If multiple tanks are involved this process is repeated for each tank and the sum of the quantity transferred from each tank is the total quantity transferred. However, when multiple tanks are involved, there are numerous variations on how the total transferred quantity can be calculated. In many cases the GSV is
and mass or weight are made collectively to this quantity. Alternatively, the individual opening and closing readings can be calculated to NSV, mass or weight and totalized accordingly. The differences resulting from these variations are usually very small and it is not the intent of this standard to specify a single method for this. Examples A1 and A2 in Annex A outline two of the more commonly used methods; however, these should not be construed as the only acceptable methods. The method used for custody transfer should be that as agreed to by the commercial parties to the transaction.
) or less and assumes that the clearance sample has verified merchantable oil at least 4 inches below the tank outlet. The CTSh is not significant to these situations
include these quantities in custody transfer calculations as the volumes lost are not available again, except through refining. Any adjustments made as a result of volumetric shrinkage are strictly upon agreement of the commercial parties involved.
(crude oil systems, for example) will need to accumulate base data differently than for transfers that do not include the use of an automatic sampler. While the volume calculation procedures for movements into a tank involving an automatic sampling system will be the same, the method of collecting the base information will be different. (Movements out of a tank are less affected as there is less blending of densities taking place). However, it may be necessary to report the density, as determined from the automatic sampling system, somewhere on the measurement ticket or report. Regardless, it will still be necessary to sample the tank before and after a receipt because of the following:
d. S&W are usually only deducted on crude oil cargoes. Petroleum products are not usually corrected for S&W unless required as a commercial condition or other specific requirement; therefore net standard volume = gross standard volume.
Quantity from the tank capacity table using the liquid level gauge to enter the table. For this example, it is assumed that any correction to the gauge, due to expansion or contraction of the tape itself, has already been made. This issue is not addressed in this standard. The user should refer to the tape manufacturer’s instructions for specific details.
Not all trim (or list) corrections are volumetric. Many are linear adjustments that are made to the observed ullage. In this case, the adjustment would be made before entering the vessel’s capacity table and a volumetric adjustment would not be necessary. If a volumetric list correction was applicable, it would be applied at this point in the calculation.
Quantity from the tank capacity table using the liquid level gauge to enter the table. For this example, it is assumed that any correction to the gauge, due to expansion or contraction of the tape itself, has already been made. This issue is not addressed in this standard. The user should refer to the tape manufacturer’s instructions for specific details.
Chapter 11.1/Adjunct to ASTM D1250/Adjunct to IP 200 “C” Tables; however, this example is applicable to any CTPL/VCF that derives form these “C” tables.
kg/l 0.8831 kg/l (air) Thermal Density Coefficient / ºC 0.00100 kg/l per ºC Liquid temperature ºC 22.5ºC
temperature of 60°F. For tanks with capacity tables calculated at a reference tank shell temperature other than 60°F, the table can still be used. However, it is necessary to subtract the reference temperature from the shell temperature and then add 60 to arrive at the temperature used to enter the table. It is important to pay attention to the algebraic signs (positive or negative) when performing this calculation.
). For tanks that are not insulated, the shell temperature is a weighted average of the ambient and the product temperature based the following equation:
) is the same as the product operating temperature. If the tank is not insulated, the user should contact the company that generated the capacity table to determine what tank shell reference temperature (TSh REF) was used.
A total of 4,088.2662 barrels was deducted from this table between 4 feet 00 inches and 5 feet 00 inches for floating roof displacement based on a weight of 1,215,000 pounds and a gravity of 35.0 API. Gauged quantities above 5 feet 00 inches reflect this deduction but shall be adjusted for varying API gravities at tank temperature according to the following.”
Chapter 11.1/Adjunct to ASTM D1250/Adjunct to IP 200, Table 5A (or 5B if the tank content is a petroleum product) as shown in Table 4.
API of 40.3 falls between the observed gravities of 42.0 and 42.5, which have a difference of 0.5 gravity. To determine what 40.3 equates to as an observed gravity, calculate what 3/4 of 0.5 gravity. The calculation equates to 0.4 (rounded). Add this to the 42.0 and the observed gravity that equates to 40.3 @ 60 is 42.4 API.
to being a density in air. For example, if the density is lbs/gal @ 60ºF, then the roof weight must be in pounds and the CTPL applicable to a standard temperature of 60ºF. Additionally, this particular example will yield a roof correction in gallons. If the table units are in barrels, it will be necessary to divide the result by 42.
The designation of corrections and correction factors by abbreviations rather than words is recommended to abbreviate the expression, facilitate algebraic manipulation, and reduce confusion. While a combination of upper case, lower case, subscripted, and superscripted notation is used, upper case notation may be used as appropriate. Additional letters may be added to symbolic notations for clarity and specificity.
Corrects a volume at an observed temperature & pressure to an equivalent volume at base temperature and pressure and is equal to CTL x CPL. For the purpose of this standard, base pressure is equivalent to atmospheric pressure and the CPL factor is considered to be 1.00000; therefore, under atmospheric conditions, the CTPL and CTL will be the same value. (CTPL and CTL are referred to as VCF in some
The total volume of all petroleum liquids and sediment and water corrected by the appropriate volume correction factor (CTPL) for the observed temperature and API gravity, relative density, or density to a standard temperature such as 60ºF or 15ºC and all free water measured at observed temperature (gross standard volume plus free water).
by a National Metrology Institute (NMI) such as the National Institute of Standards and Technology (NIST) in the United States. From this level downwards, any uncertainty in a higher level must be reflected in all lower levels as a bias or systematic error. Whether such bias will be positive or negative is unknown as uncertainty carries either possibility.
To expect equal or less uncertainty in a lower level of the hierarchy than exists in a higher level is unrealistic. The only way to decrease the random component of uncertainty in a given measurement system is to increase the number of determinations and then find their mean value. The number of digits in intermediate calculations of a value can be larger in the upper levels of the hierarchy than in the lower levels, but the temptation to move towards imaginary significance (more decimal places) must be tempered or resisted by a wholesome respect for realism.
“The standard for determining CTL factors is the computer subroutine implementation procedures of API MPMS Chapter 11.1, Volume X. When fully implemented, this generates a CTL factor of five significant digits. That is, five decimal digits at temperatures above standard temperature (60ºF and 15ºC) and four decimal digits at temperatures below standard temperature. Use of the printed table limits the user to
one step to the number of figures that are to be recorded and shall not be rounded in two or more steps of successive rounding. In absolute terms, when the figure to the right of last place to be retained is 5 or greater, the figure in the last place to be retained should be increased by 1. If the figure to the right of the last place to be retained is less than 5, the figure in the last place retained should be unchanged.
document does not address how these data are obtained. That information is found in the referenced publications listed in Section 2, and it is assumed, for the purpose of this document, that all such data have been obtained in accordance with these referenced publications. It should be understood that the observed data must be gathered concurrently. In other words, the level gauge, water cut, temperature, and so forth should all be taken at the same time for inclusion on the same measurement ticket or ullage report.
Innage or ullage or liquid level Innage or ullage of liquid level Innage or ullage of free water level Innage or ullage of free water level
Average liquid temperature ºF or ºC Average liquid temperature ºF or ºC Observed density @ sample temperature Observed density @ sample temperature Percentage of sediment and water Percentage of sediment and water Ambient air temperature Forward draft reading
Storage tanks differ from test measures in size and wall thickness. Differences also occur because the tanks cannot readily be sheltered from the elements. Therefore, ambient temperatures as well as product temperatures must be considered when calculating an appropriate correction for the effect of temperature on the shell of the tank. The correction factor for the effect of temperature on the shell of the tank is called CTSh and may be calculated by the following:
) is usually stated on the capacity table. If this is not the case, contact the company that generated the table. Some capacity tables make reference to an operating product temperature; this should not be confused with the Tank Shell Reference Temperature (TSh REF), which is a tank shell temperature.
rises or decrease as the temperature falls. The volume change is proportional to the thermal coefficient of expansion of the liquid, which varies with density (API gravity) and temperature. The correction factor for the effect of the temperature and pressure on a volume of liquid is called CTPL, CTL or VCF. The function of this correction factor is to adjust the volume of liquid at observed temperature to its volume at a standard temperature. The most common standard temperatures are 60ºF, 15ºC, and 20ºC (68ºF).
developed by the manufacturer. These are usually in the form of product specific tables of CTL (VCF), showing the factor at observed temperatures, which must be applied to obtain the volume at standard temperature; or, a volume correction factor, per degree difference in observed temperature. While these individual tables can have their own parameters and table entry requirements, their application is the same.
referred to in this document, mass will refer to weight in vacuum (vacuo) and weight will refer to weight in air. If the same material is measured in a vacuum and then in air, the measured quantity in air will be lighter than that of the measured quantity in vacuum by an amount equal to the volume of air displaced by the material being measured. In other words the weight measured in air is affected by the “buoyancy” of the air surrounding the object.
density materials will displace less air than low density materials; therefore, the difference between weight in air and weight in vacuum varies with density and will have the greatest impact on low density materials. While this difference is not large, it is measurable and typically impacts the third and fourth decimal place of the density, by an amount shown in the table below.
are not uncommon, especially in the chemical industry. When adjusting a density in vacuum to its corresponding density in air, the correction is subtracted. When adjusting a density in air to its corresponding density in vacuum, the
necessary to obtain all the observed information that will be needed in order to calculate a net volume. It is the user’s responsibility to obtain that information from the standards referenced earlier. While there are some precautionary notes in the text of this document, it is assumed that the user will come to this standard with all the observed information necessary to begin to calculate net volumes. The information needed is liquid level, FW level, product temperature, ambient temperature, density, and S&W percentage. It will also be necessary to have the capacity table and applicable correction factor tables or
contents are not in motion. The calculation of transferred volumes for custody transfer typically involves performing the same calculation before and after a transfer and determining the difference. If multiple tanks are involved this process is repeated for each tank and the sum of the quantity transferred from each tank is the total quantity transferred. However, when multiple tanks are involved, there are numerous variations on how the total transferred quantity can be calculated. In many cases the GSV is
and mass or weight are made collectively to this quantity. Alternatively, the individual opening and closing readings can be calculated to NSV, mass or weight and totalized accordingly. The differences resulting from these variations are usually very small and it is not the intent of this standard to specify a single method for this. Examples A1 and A2 in Annex A outline two of the more commonly used methods; however, these should not be construed as the only acceptable methods. The method used for custody transfer should be that as agreed to by the commercial parties to the transaction.
(crude oil systems, for example) will need to accumulate base data differently than for transfers that do not include the use of an automatic sampler. While the volume calculation procedures for movements into a tank involving an automatic sampling system will be the same, the method of collecting the base information will be different. (Movements out of a tank are less affected as there is less blending of densities taking place). However, it may be necessary to report the density, as determined from the automatic sampling system, somewhere on the measurement ticket or report. Regardless, it will still be necessary to sample the tank before and after a receipt because of the following:
Quantity from the tank capacity table using the liquid level gauge to enter the table. For this example, it is assumed that any correction to the gauge, due to expansion or contraction of the tape itself, has already been made. This issue is not addressed in this standard. The user should refer to the tape manufacturer’s instructions for specific details.
temperature of 60°F. For tanks with capacity tables calculated at a reference tank shell temperature other than 60°F, the table can still be used. However, it is necessary to subtract the reference temperature from the shell temperature and then add 60 to arrive at the temperature used to enter the table. It is important to pay attention to the algebraic signs (positive or negative) when performing this calculation.
) is the same as the product operating temperature. If the tank is not insulated, the user should contact the company that generated the capacity table to determine what tank shell reference temperature (TSh REF) was used.
A total of 4,088.2662 barrels was deducted from this table between 4 feet 00 inches and 5 feet 00 inches for floating roof displacement based on a weight of 1,215,000 pounds and a gravity of 35.0 API. Gauged quantities above 5 feet 00 inches reflect this deduction but shall be adjusted for varying API gravities at tank temperature according to the following.”
To expect equal or less uncertainty in a lower level of the hierarchy than exists in a higher level is unrealistic. The only way to decrease the random component of uncertainty in a given measurement system is to increase the number of determinations and then find their mean value. The number of digits in intermediate calculations of a value can be larger in the upper levels of the hierarchy than in the lower levels, but the temptation to move towards imaginary significance (more decimal places) must be tempered or resisted by a wholesome respect for realism.
“The standard for determining CTL factors is the computer subroutine implementation procedures of API MPMS Chapter 11.1, Volume X. When fully implemented, this generates a CTL factor of five significant digits. That is, five decimal digits at temperatures above standard temperature (60ºF and 15ºC) and four decimal digits at temperatures below standard temperature. Use of the printed table limits the user to
document does not address how these data are obtained. That information is found in the referenced publications listed in Section 2, and it is assumed, for the purpose of this document, that all such data have been obtained in accordance with these referenced publications. It should be understood that the observed data must be gathered concurrently. In other words, the level gauge, water cut, temperature, and so forth should all be taken at the same time for inclusion on the same measurement ticket or ullage report.
Storage tanks differ from test measures in size and wall thickness. Differences also occur because the tanks cannot readily be sheltered from the elements. Therefore, ambient temperatures as well as product temperatures must be considered when calculating an appropriate correction for the effect of temperature on the shell of the tank. The correction factor for the effect of temperature on the shell of the tank is called CTSh and may be calculated by the following:
rises or decrease as the temperature falls. The volume change is proportional to the thermal coefficient of expansion of the liquid, which varies with density (API gravity) and temperature. The correction factor for the effect of the temperature and pressure on a volume of liquid is called CTPL, CTL or VCF. The function of this correction factor is to adjust the volume of liquid at observed temperature to its volume at a standard temperature. The most common standard temperatures are 60ºF, 15ºC, and 20ºC (68ºF).
referred to in this document, mass will refer to weight in vacuum (vacuo) and weight will refer to weight in air. If the same material is measured in a vacuum and then in air, the measured quantity in air will be lighter than that of the measured quantity in vacuum by an amount equal to the volume of air displaced by the material being measured. In other words the weight measured in air is affected by the “buoyancy” of the air surrounding the object.
necessary to obtain all the observed information that will be needed in order to calculate a net volume. It is the user’s responsibility to obtain that information from the standards referenced earlier. While there are some precautionary notes in the text of this document, it is assumed that the user will come to this standard with all the observed information necessary to begin to calculate net volumes. The information needed is liquid level, FW level, product temperature, ambient temperature, density, and S&W percentage. It will also be necessary to have the capacity table and applicable correction factor tables or
contents are not in motion. The calculation of transferred volumes for custody transfer typically involves performing the same calculation before and after a transfer and determining the difference. If multiple tanks are involved this process is repeated for each tank and the sum of the quantity transferred from each tank is the total quantity transferred. However, when multiple tanks are involved, there are numerous variations on how the total transferred quantity can be calculated. In many cases the GSV is
and mass or weight are made collectively to this quantity. Alternatively, the individual opening and closing readings can be calculated to NSV, mass or weight and totalized accordingly. The differences resulting from these variations are usually very small and it is not the intent of this standard to specify a single method for this. Examples A1 and A2 in Annex A outline two of the more commonly used methods; however, these should not be construed as the only acceptable methods. The method used for custody transfer should be that as agreed to by the commercial parties to the transaction.
(crude oil systems, for example) will need to accumulate base data differently than for transfers that do not include the use of an automatic sampler. While the volume calculation procedures for movements into a tank involving an automatic sampling system will be the same, the method of collecting the base information will be different. (Movements out of a tank are less affected as there is less blending of densities taking place). However, it may be necessary to report the density, as determined from the automatic sampling system, somewhere on the measurement ticket or report. Regardless, it will still be necessary to sample the tank before and after a receipt because of the following:
To expect equal or less uncertainty in a lower level of the hierarchy than exists in a higher level is unrealistic. The only way to decrease the random component of uncertainty in a given measurement system is to increase the number of determinations and then find their mean value. The number of digits in intermediate calculations of a value can be larger in the upper levels of the hierarchy than in the lower levels, but the temptation to move towards imaginary significance (more decimal places) must be tempered or resisted by a wholesome respect for realism.
“The standard for determining CTL factors is the computer subroutine implementation procedures of API MPMS Chapter 11.1, Volume X. When fully implemented, this generates a CTL factor of five significant digits. That is, five decimal digits at temperatures above standard temperature (60ºF and 15ºC) and four decimal digits at temperatures below standard temperature. Use of the printed table limits the user to
necessary to obtain all the observed information that will be needed in order to calculate a net volume. It is the user’s responsibility to obtain that information from the standards referenced earlier. While there are some precautionary notes in the text of this document, it is assumed that the user will come to this standard with all the observed information necessary to begin to calculate net volumes. The information needed is liquid level, FW level, product temperature, ambient temperature, density, and S&W percentage. It will also be necessary to have the capacity table and applicable correction factor tables or
and mass or weight are made collectively to this quantity. Alternatively, the individual opening and closing readings can be calculated to NSV, mass or weight and totalized accordingly. The differences resulting from these variations are usually very small and it is not the intent of this standard to specify a single method for this. Examples A1 and A2 in Annex A outline two of the more commonly used methods; however, these should not be construed as the only acceptable methods. The method used for custody transfer should be that as agreed to by the commercial parties to the transaction.
(crude oil systems, for example) will need to accumulate base data differently than for transfers that do not include the use of an automatic sampler. While the volume calculation procedures for movements into a tank involving an automatic sampling system will be the same, the method of collecting the base information will be different. (Movements out of a tank are less affected as there is less blending of densities taking place). However, it may be necessary to report the density, as determined from the automatic sampling system, somewhere on the measurement ticket or report. Regardless, it will still be necessary to sample the tank before and after a receipt because of the following:
(crude oil systems, for example) will need to accumulate base data differently than for transfers that do not include the use of an automatic sampler. While the volume calculation procedures for movements into a tank involving an automatic sampling system will be the same, the method of collecting the base information will be different. (Movements out of a tank are less affected as there is less blending of densities taking place). However, it may be necessary to report the density, as determined from the automatic sampling system, somewhere on the measurement ticket or report. Regardless, it will still be necessary to sample the tank before and after a receipt because of the following: