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I ^J IhI3 I National Institute of Standards and Technology

NJST

PUBLICATIONS

NIST Technical Note 1270

Measurements of Coefficients of Disciiarge for

Concentric Fiange-Tapped Square-Edged Orifice

l\/leters in Naturai Gas Over tlie Reynoids Number

Range 25,000 to 16,000,000

James R. Whetstone, William G. Cleveland, Blaine R. Bateman,

and Charles F. Sindt
T

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NIST Technical Note 1270

Measurements of Coefficients of Disciiarge for

Concentric Fiange-Tapped Square-Edged Orifice

l\/leters in Naturai Gas Over ttie Reynolds Number

Range 25,000 to 16,000,000

James R. Whetstone, William G. Cleveland, Blaine R. Bateman, and Charles F. Sindt

Chemical Process Metrology Division Center for Chemical Engineering

National Engineering Laboratory

National Institute of Standards and Technology

Gaithersburg, MD 20899

September 1989

o

a^^'^'co^

\

c

NOTE: As of 23 August 1988, the National Bureau of Standards (NBS) became the National Institute of Standards and Technology (NIST) when President

Reagan signed into law the Omnibus Trade and

Competitiveness Act.

U.S. Department of Commerce

Robert A. Mosbacher, Secretary

National Institute of Standards and Technology

Raymond G, Kammer, Acting Director
National Institute of Standards U.S. Government Printing Office For sale by the Superintendent

and Teclinology Washington: 1989 of Documents

Technical Note 1270 U.S. Government Printing Office

Natl. Inst. Stand. Technol. Washington, DC 20402

Tech. Note 1270

364 pages (Sept. 1989)

CODEN: NTNOEF
Measurements of Coefficients of Discharge

for Concentric, Flange-Tapped, Square-Edged Orifice Meters

In Natural Gas Over the Reynolds Number Range 25,000 to 16,000,000

James R. Whetstone, William G. Cleveland,

Blaine R. Bateman, Charles F. Sindt

Abstract

This report describes the data acquisition systems and procedures used

in the American Petroleum Institute (API) -sponsored orifice discharge

coefficient project performed in natural gas flows and conducted at the

test loop of the Natural Gas Pipeline Company of America (NGPL) in

Joliet, Illinois. These systems follow the general design philosophy of

the companion intermediate Reynolds number project conducted in water

flows [1]. NBS provided the measurement and data acquisition systems,

maintained the resulting database, and calculated the results from that

database

Measurements of orifice discharge coefficients for 6- and 10-inch

diameter orifice meter runs were made using critical Venturis for mass flowrate measurement with associated measurement of pressures and

temperatures. Eleven Venturis were calibrated at the Colorado

Engineering Experiment Station, Inc. (CEESI) . Measurements of absolute

and differential pressure and temperature for venturi and orifice meter

conditions were made using an automated data acquisition system.

Temperature and pressure measurements were directly related to U.S.

national measurement standards. Daily calibration of absolute and

differential pressure transducers using pressure working standards was designed into the measurement procedures.

Natural gas compositions were measured using on-line gas chromatography

based on gravimetrically-prepared gas standards having compositions

closely similar to those of the two gas stream compositions used.

Calculations of natural gas density and viscosity were made using a recently developed state-of-the-art equation of state [2] and a corresponding-states model of transport properties [3].

Collected over a 2-year period, the database contains tests on 44

orifice plates in 8 beta ratios for two meter sizes (6- and 10-inches).

The database contains 1,345 valid test points.

NOTE: On August 23, 1988 with the signing of the Omnibus Trade and

Competitiveness Act, the National Bureau of Standards (NBS) became the

National Institute of Standards and Technology (NIST) . Since this

report was written and reviewed before this change, references to NBS in

the body of the report have not been changed to NIST.

Ill

Measurements of Coefficients of Discharge

for

Concentric, Flange -Tapped, Square -Edged Orifice Meters

in Natural Gas

Over the Reynolds Number Range 25,000 to 16,000,000

CONTENTS

Page

I . Introduction 1 II. Experimental Facilities and Measurement Systems 4

A. General Description of the Experimental Apparatus and

Test Flow Loop 6

B. Sensitivity Analysis of the Measurement System and

Variation of the Discharge Coefficient with Various

Parameters 6

C. Natural Gas Mass Flowrate Measurement System and

Uncertainty 12

1

.

General Description 12

2. Natural Gas Mass Flowrate Calculation and Nozzle

Discharge Coefficient Values 12

3. Uncertainty in the Nozzle Discharge Coefficient

Value 14

D. Static and Differential Pressure Measurement Systems and

Standards 18

1. Pressure Measurement Requirements and Units 18

2

.

Differential Pressure Transducers 18

3

.

Static Pressure Transducers 22

4. Working Pressure Standards 22

5

.

Static Pressure Working Standard 23

6. Uncertainty in the Static Pressure Working Standard .. 25

7. Barometric Pressure Measurement and Its Uncertainty . 27

8. Uncertainty in the Differential Pressure Working

Standard 27

9. Pressure Transducer Calibration Procedures 29

a. Differential Pressure Transducer Calibration

Procedures 29

b. Static Pressure Transducer Calibration Procedures 32

10. Transducer Response Functions and Coefficient Values 33

11. Estimated Uncertainty in the Measurement of Orifice

Meter Differential Pressures %: • • • ^^

12. Estimated Uncertainty in the Measurement of

Orifice Meter and Critical Venturi Absolute

Pressures 38

13. Summary of Transducer Identifications and Measurement

Parameters 39

V
E. Temperature Measurements and Uncertainties 40

1. Thermometer Location, Calibration, and Time in

Service 40

2

Temperature Measurement Uncertainty 43

F. Natural Gas Composition Measurements - Gas Chromatography

System 44

1. Chromatograph Description, Calibration Gas

Composition, and Sample Gas-Handling Procedures 44

2

Gas Analysis Reproducibility 46

G. Orifice Meter Installation and Dimensional Measurements .

48

1Orifice Meter Tube and Flow Conditioner Geometrical

Characteristics and Dimensional Measurements 49

2. Orifice Plate Dimensional Measurements and

Uncertainties 58

III. Calculation of the Mass Flowrate of Natural Gas Through

Critical Flow Nozzles and Natural Gas Physical Property

Values and Their Uncertainty 65

A. Derivation of Basic Equations for Gas Flowrate Through

Critical Flow Nozzles 65

B. Derivation of Critical Flow Factor Equations 67

C. Description of Mass Flowrate Algorithm to Compute

Results for One Run 67

D. Comparison of Computed and Experimental Values 68

E. Effect of Compositional Uncertainty on Computed Values ... 71

F. Uncertainty in Natural Gas Density and Critical Flow

Factor Due to Temperature and Pressure Uncertainties 71

G. Determination of Viscosity for Calculation of Reynolds

Number 71

IV. Calculation of the Uncertainty in Orifice Discharge

Coefficient Values Using the Propagation-of-Errors Method .... 72

A. Analysis of the Total Mass Flowrate Measurement

Uncertainty 73

1. Uncertainty in the Total Mass Flowrate Through the

Orifice 73

2. Uncertainty in the Mass Flowrate Through a Single

Critical Nozzle 74

B. Relative Uncertainty in the Orifice and Meter Tube

Diameter Values 81

C. Relative Uncertainty in Natural Gas Density at the

Orifice Meter Due to Temperature and Pressure

Uncertainty 81

D. Uncertainty in the Differential Pressure 81

E. Uncertainty in the Expansion Factor 81

F. Uncertainty in Orifice Meter Discharge Coefficient 82

G. Example Calculation of Uncertainty Components for One

Test Run 83

1. Computation of Uncertainty in the Nozzle Mass

Flowrate 85

2Computation of the Uncertainty in Orifice

Parameters 88

3

Computation of the Uncertainty in the Orifice

Discharge Coefficient 89

VI
V. Data Acquisition and Control Systems 90

A. General Description 90

B. Data Acquisition System Hardware 90

C. Data Acquisition System Software 91

VI

.

Calibration and Test Procedures 95

A. Pressure Transducer Calibration 96

B. Orifice Meter Data Acquisition Procedures 99

VII. Operating Procedures, Test Run Inventory, Test Run Data

Analysis Results, and Analysis of the Results 103

A. Operating Schedule, Final Database Definition, and

Archiving of the Database 103

B. Inventory of the Final Database 105

C. Presentation of the Data Analysis Results 116

D. Test Run Result Analysis and Discussion 201

1

.

Discussion of Test Results - FE-7ABC 201

2. Discussion of Test Results - PE-8ABC 203

3. Discussion of Test Results - FE-9ABC 204

4. Discussion of Test Results - FE-OABC 206

VIII . Archiving of the Database 207

IX. Acknowledgments 208

X. References 210

Appendices

Appendix A - API Natural Gas Test Facility, Natural Gas Pipeline

Company of America, Joliet, Illinois, System and

Piping Configuration Description 1984 and 1985

Combined Report 213

Appendix B - Operational History of the Project 259

Appendix C - Derivation of the Coefficient of Discharge Relation

and Associated Units Conversion Factors 287

Appendix D - Report to the American Petroleum Institute on Experimental and Computed Values of Natural Gas

Compressibility for Samples of Gas Similar to Those

Used in the Joliet Orifice Meter Testing Program 293

Appendix E - Database Structures 323

Appendix F - Report of Calibration of the 0.125 Nozzle ... 327

Appendix G - Archival Database Structure and Format 335

Vll
List of Figures Page

Figure 1. Schematic diagram of the natural gas test loop's major

components 5

Figure 2. Orifice meter discharge coefficient measurement system

and parameters 7

Figure 3. Orifice meter flow measurement data acquisition systems 8

Figure 4. Differential pressure transducer manifold schematic

diagram 21

Figure 5. Orifice meter tube dimensional measurement locations ... 50

Figure 6 . Photograph of internal micrometer 52

Figure 7. Comparison of experimental and calculated sonic

velocity data 69

Figure 8. Block diagram of transducer calibration software system . 97

Figure 9 . Data acquisition software block diagram 100

Figure 10. (A through H) Discharge coefficient/Reynolds ntimber

plots, FE-7ABC, 6-lnch meter tube, 15 orifice plates... 144

Figure 11. (A through D) Discharge coefficient/Reynolds number

plots, PE-8ABC, 6-inch meter tube, 7 orifice plates.... 161

Figure 12. (A through E) Discharge coefficient/Reynolds number

plots, FE-9ABC, 10-inch meter tube, 10 Orifice plates... 178

Figure 13. (A through F) Discharge coefficient/Re3molds number

plots, FE-OABC, 10-inch meter tube, 12 Orifice plates... 195

VI 11
List of Tables Page

Table 1. Typical compositions of the gulf coast and Amarillo

natural gas sources 4

Table 2. Coefficients of the nozzle discharge coefficient model . 13

Table 3. Pressure gauge weight mass values, maker number 76837 .. 24

Table 4. Relative uncertainty in the static pressure working

standard 27

Table 5. Calibration results for the differential pressure

working standard 28

Table 6. Differential pressure transducer calibration schedules . 30

Table 7. Differential pressure transducer calibration data for

August 9, 1985 at a static pressure of 580 psig 31

Table 8. Calibration data for the static pressure transducers

for August 9 , 1985 32

Table 9. Transducer response coefficients for the orifice

static pressure measurement transducer serial

number 541529 34

Table 10. Response Coefficients for differential pressure

transducers HW-003 and HW-004 36

Table 11. Thermometer coefficients and locations for the 1984

database 41

Table 12. Thermometer coefficients and locations for the 1985

database before October 2 , 1985 42

Table 13. Thermometer coefficients and locations for the 1985

database after October 2 , 1985 42

Table 14. Gas chromatograph reference gas sample composition 45

Table 15. Repeated analyses of blocked line containing gulf

coast gas 47

Table 16. Repeated analyses of gulf coast gas sample 47

Table 17. Orifice meter diameter measurements made at NBS in 1984

and early 1985 55

Table 18. Orifice meter tube diameter measurements made by NGPL

personnel at the Joliet test site prior to installation. 56

Table 19. Orifice meter tube diameter measurements after honing

and before electroless nickel plating 59

ix
Table 20. Orifice meter tube diameters in the plane of the tap

hole centerlines (axial position 1) 61

Table 21. Orifice plate initial dimensional measurement results ., 63

Table 22. Confirmatory plate diameter and flatness measurements .. 64

Table 23. Comparison of experimental and computed compressibility

values for the gulf coast chromatograph calibration

gas 70

Table 24. Maximum values of the partial derivatives of the

critical flow factor and density of natural gas

with respect to mole fraction, pressure, and

temperature 78

Table 25. Repeated measured compositions of gulf coast gas taken

from a sample bottle 79

Table 26. Systematic errors in the two chromatograph gas

standards 80

Table 27 . Inventory of observation runs 106

Table 28. (A through 0) Orifice Discharge Coefficient values,

meter tube FE-7ABC 118

Table 29. (A through G) Orifice discharge coefficient values,

meter tube PE-8ABC 152

Table 30. (A through J) Orifice discharge coefficient values,

meter tube FE-9ABC 165

Table 31. (A through L) Orifice discharge coefficient values,

meter tube FE-OABC 183

X
List of Symbols Used in Mathematical Formulas

a - area thermal coefficient for the ceramic ball/stainless

nozzle combination of the deadweight tester

Ajj - area of the ball of a deadweight tester

A^ - area of the meter tube

A2 - area of the orifice

A^ - nozzle throat area

C* - critical factor for gas flowing through a critical nozzle

Cj - discharge coefficient, orifice or nozzle depending on context

Cp - specific heat of fluid at constant pressure,

Cy - specific heat of fluid at constant volume,

d - diameter of the orifice or nozzle depending upon the

context

dg - diameter of a nozzle during calibration

d„ - density of the weight material of a mass standard

D - the diameter of the meter tube

Fg - orifice thermal expansion factor

F^ - diametral thermal expansion factor

g

- acceleration of gravity

G^. - mass flow rate per unit area

IL - nozzle plenum enthalpy

h - enthalpy of the flowing fluid per unit mass,

H^ - nozzle throat enthalpy

•m - mass flow rate

m^ - mass flow rate in the meter tube

mg - mass flow rate through the orifice

m, - theoretical mass flow rate

XI
M - observed mass value

Mg - apparent mass of the weight stack on deadweight tester

M^ - true mass of the weight stack

N - a constant whose value depends upon the units of the

measured parameters

P - pressure in the general case

Pj - total pressure at the upstream orifice tap

?2 ~ total pressure at the downstream orifice tap

P - nozzle plenum absolute pressure

R - universal gas constant, also resistance in ohms of a platinum resistance thermometer

Rp - pipe Reynolds number

R(j - nozzle throat Reynolds number

r - P1/P2 . the ratio of the pressure at the downstream

pressure tap to that at the upstream pressure tap,

s - entropy of the flowing fluid per unit mass,

s - total relative uncertainty in the orifice discharge

s _ - residual standard deviation of the fit for the nozzle

^ discharge coefficient divided by the discharge coefficient

in percent coefficient expressed in percent

s - random uncertainty in the orifice or nozzle discharge

coefficient in percent ^ds - systematic uncertainty in the orifice or nozzle discharge

•* coefficient in percent

S(,* - relative uncertainty in the critical flow factor in percent

Sc*j. - random uncertainty in the nozzle plenxim pressure in percent

^c*s " systematic uncertainty in the nozzle plenum pressure in

percent

s j J. - random uncertainty in percent for the j th parameter

relative to that parameter

s j

g - systematic uncertainty in percent for the jth parameter

relative to that parameter

Xll
s^ - relative uncertainty in the nozzle mass flow rate value in

percent

s^j. - random uncertainty in the total mass flow rate in the

system in percent

s^g - systematic uncertainty in the total mass flow rate in the

system in percent

^NA " systematic nozzle area uncertainty

Sp - relative uncertainty in the nozzle pressure value in

percent

Spj, - uncertainty in the difference pressure applied to the

transducers

Spj - residual standard of the fit for a static pressure

transducer

^Pm ~ standard deviation of the mean static pressure value taken

during a test run

Spj. - random uncertainty in the nozzle plenum pressure in

percent

Spg - systematic uncertainty in the nozzle plenum pressure in

percent

Sj - relative uncertainty in the temperature in percent

s^^ - standard deviation of the mean temperature divided by the

mean temperature in percent

Sjj. - random uncertainty in the nozzle plenum temperature in

percent

^Ts ~ systematic uncertainty in the nozzle plenum temperature in

percent

Spj. - random uncertainty in the gas density at the orifice

conditions in percent

s^g - systematic uncertainty in the gas density at the orifice

conditions in percent

'^APf " residual standard deviation of the fit for a differential

pressure transducer

'^APm " standard deviation of the mean of a set of differential

pressure observations taken during a test run

^APr " i^andom uncertainty in the differential pressure in percent

Xlll
^APs " systematic uncertainty in the differential pressure in

percent

s„ - uncertainty in the mass standards

S - nozzle plenum entropy

S^. - nozzle throat entropy

s - random uncertainty in the nozzle plenum pressure in percent

s - systematic uncertainty in the nozzle plenum pressure in

j percent

T - temperature generally, may be absolute depending upon

context

T^ - temperature of air

T - nozzle plenum absolute temperature

T^ - nozzle throat absolute temperature

u - internal energy of the flowing fluid per unit mass

xi^ - sonic velocity of the gas in the throat of a nozzle

V - Ruska transducer voltage

Vq - Ruska transducer voltage at zero differential pressure

^1 '^2 " velocity of the flowing fluid

Y - adiabatic expansion factor

W - tare force of the deadweight tester

Z - compressibility factor

a - coefficient of thermal expansion of a nozzle

fi - d/D, the orifice beta ratio,

7

- Cp/Cy, the ratio of specific heats,

AP - P^ - P2 , the differential pressure developed across the

orifice meter.

AS - change in entropy

AH - change in enthalpy

Pi - density of the fluid flowing in the meter tube,

xiv
P2 - density of the fluid flowing in the orifice,

Pt - density of the fluid flowing in the nozzle throat,

fi - absolute viscosity

XV

Measurements of Coefficients of Discharge

for Concentric, Flange-Tapped, Square-Edged Orifice Meters

in Natural Gas Over the Reynolds Number Range 25,000 to 16,000,000

I . Introduction

For the last two decades it has been recognized in the flowmetering

community that a need exists for we 11 -documented, experimental databases

of coefficients of discharge for orifice meters in order to achieve a greater degree of accuracy in custody transfer measurements. The

American Petroleum Institute (API) and the American Gas Association

(AGA) made an initial attempt to resolve the situation for flange -tapped

orifice meters in the mid-1970' s; however, this attempt did not come to

fruition. A subsequent effort was made by API and the Gas Processors

Association (GPA) to develop a comprehensive and well- documented

database of discharge coefficients for flange-tapped orifice meters

spanning their range of use. The three major parameters to be varied

were the Reynolds number, the meter tube diameter, and the ratio of the

orifice diameter to the pipe diameter (known as the beta ratio) . To

accomplish this objective a program consisting of three projects was

planned. Common to the program would be a set of orifice meters

comprised of meter tubes in five sizes with each size having sets of seven orifice plates with a beta ratio range from 0.1 to 0.75. Each

project would concentrate on one region of the Reynolds niomber range by

using a particular fluid for flow tests. The fluids were selected on a practical basis, and the three projects were designed so that data

developed by any one project would overlap that developed by a companion

project in the adjacent Reynolds range. The low Reynolds number project

would be performed using a moderate viscosity liquid and the smaller

diameter orifice meters. The intermediate Reynolds niomber project would

use water as the test fluid and would involve all orifice meters. The

high Reynolds number project reported here would use natural gas and the

larger orifice meters.

The high Reynolds number project differed from the other two projects in

that the API entered into two contractual agreements to perform the

work. In 1983 the U.S. National Bureau of Standards (NBS) and the API

agreed that NBS (1) would supply a documented measurement system for use

in the high Reynolds number project, (2) would reduce the data derived

from the test observations, and (3) would supply that data to API and

make it part of the public domain. The flow testing site was that of

the Natural Gas Pipeline Company of America (NGPL) located near Joliet,

IL. NGPL was responsible for the day-to-day operation of the tests and

provided the critical Venturis and their calibration for use as the mass flow rate measurement standards. Funded by the Gas Research Institute,

the Colorado Engineering Experiment Station, Inc. (CEESI) performed the

calibrations of the critical Venturis.

This report describes the measurement systems provided by NBS, the

operation of the tests, the flow control and measurement system (in

sufficient detail to discuss the results of the testing program) , and

the results of the testing program. The approach taken by NBS was to

document the measurement procedures and standards and relate them to
U.S. national standards maintained by NBS for all of the measured

parameters except mass flow rate.

As with any database development or research project, a set of initial

assuimptions and conditions are necessary to form the basic framework

within which the project operates and its goals are accomplished. The

following is written to describe this framework. During the course of

the project some of the specific conditions, procedures and methods

changed. However, the basic framework and objective of the project

remained essentially constant.

The rationale for the configurations of the orifice meters and the

measurement system was the following:

• A primary condition of the project was that it would develop a fundamental discharge coefficient database. Effects on the

orifice meter from a variety of extraneous sources not associated

with the fundamental orifice meter configuration were to be

eliminated or their effect minimized.

• Two orifice meter sizes were used in this project. These had

nominal diameters of 6 and 10 inches^ . In each size a single

level of redundancy would be realized, i.e. , two meter tubes at

each size would comprise a meter tube assembly. Flange taps would

be used to reflect the preponderance of U.S. commercial practice.

• Each meter tube size would have two sets of orifice plates having

beta ratios ranging from nominally 0.1 to 0.75. Each set would be

nominally identical in a particular size and each set was used with

a single meter tube with one exception.

• The manufactured quality of the meter tubes and orifice plates was

to be of commercial quality in order to reflect a level of

variability normally seen in commercial metering installations.

Therefore, the meter tubes were constructed of seamless steel

tubing, and fitted with ANSI 600 psi steel flanges. However, a departure from commercial practice was made in the types of flange

seals. Rather than the compression gasket seals normally used in

commercial orifice metering, o-ring seals were used. The o-ring

grooves were placed in each interior flange of the three section

meter tube set. The use of o-ring seals provided a reproducible

method for locating the pressure taps relative to the orifice

plate. This also eliminated any step in the diameter between the

meter tube and the orifice, and eliminated the question of the

effect of gaskets of variable thickness and diameter on the

discharge coefficients calculated from the database.

• The maximum differential pressure would be approximately 200

inches of water or 7 . 5 psid. The minimum differential pressure

would be determined by the capability of the measurement system.

To conform with the sponsor's request, English units are used throughout

this report. This procedure departs from the normal NBS practice of

using SI units in its technical publications.
• Where feasible, state-of-the-art measurement techniques would be

employed.

• All measured parameters were to be referred directly to U.S.

standards of measurements.

• Documentation of the measurement systems and procedures was to be

as complete as possible.

• In an attempt to isolate the orifice meter from effects caused by

the installation of the orifice meters in the test facility, a flow

conditioner and an approach tube (approximately 40 diameters long)

were added to the normal commercial meter tube configuration.

In planning this project it was decided that the amount of data acquired

manually would be minimized. In particular, all pressure and temperature measurements would be automated to minimize human error. As a consequence, the rate at which differential pressure values could be

acquired was much larger than in previously reported work, and each of

these values was recorded on magnetic media. Therefore, the database

that has resulted from this project is quite voluminous and cannot be

included in its entirety in this report. Omitted from this report are

the observations of each differential pressure, static pressure, and

temperature recorded for each test run by the data acquisition system.

However, the entire database is available in computer- readable form.

The structures of the database are given here and the database itself is

available from the API.

Computations of the results of the tests are closely related to the

calculation of the physical properties of natural gas. A state-of-theart equation of state for natural gas [2] and a state-of-the-art program

for computing transport properties [3] were used in computing the final

results. Results for the test runs taken during the summer and fall of

1984 and 1985 are included in the report. Excluded from these results

are those runs made invalid by operator error or measurement equipment

malfunction.

This report has been written with several objectives. In addition to

the need to report the data and results accurately, considerable effort

has gone into the presentation of the procedures and methods used in

acquisition of the observational database. A primary objective in

planning and executing the project was to fully document the work in

such a way that those interested in evaluating the basis for the

project's results could do so to a level of detail similar to that used

in its execution. The driving force behind this requirement has been

the lack of detailed descriptions of the previous work [4] upon which

presently used correlations [5,6] of orifice discharge coefficients are based. To a large extent the justification for the orifice meter

database program, of which this project is a part, is the lack of such

information in the current world database. Therefore, this report has

been written with considerable detail so that future workers in the

field may profit from it.
II. Experimental Facilities and Measurement Systems

The tests were conducted using the Natural Gas Pipeline Company of

America's (NGPL) natural gas test loop located at their Joliet, IL

station. A description of this facility written by the NGPL Principal

Investigator for this project, Mr. G. G. Less, is given in Appendix A.

Excerpts from that report are given here to clarify the descriptions of

the experimental configurations and procedures.

NGPL's Joliet station is located at the junction of two major natural

gas transmission lines as shown in figure 1. One supplies natural gas

produced along the U.S. gulf coast; this will be designated Gulf Coast

Gas. The other originates near and supplies natural gas produced in the

Texas panhandle region near Amarillo, TX; this will be designated

Amarillo Gas. The compositions of the two sources of natural gas differ

significantly in methane and nitrogen content. Typical analyses of the

compositions taken from two test runs are given in table 1. Variations

in the gas compositions of each stream were considerably smaller than

the between- stream differences.

Table 1, Typical compositions of the gulf coast

and Amarillo natural gas sources

Gas Gulf Coast Amarillo

Component Gas Gas

Mole Percent Mol(e Percent

Methane 95.966 90.639

Ethane 2.092 4.566

Propane 0.472 0.824

I -Butane 0.105 0.103

N- Butane 0.102 0.147

I-Pentane 0.046 0.040

N-Pentane 0.028 0.034

C6 Plus 0.065 0.039

Nitrogen 0.347 3.136

Carbon dioxi de 0.776 0.472

The natural gas test loop was installed in parallel with NGPL's mainline

regulators such that the natural gas from either source could pass

through the loop. The test loop was arranged such that inlet gas

pressures from 450 to 750 psig and outlet pressures from 385 to 415 psig

were available. This arrangement allowed the use of critical- flow

Venturis as flow measurement standards. For the series of tests

reported here, the test loop was modified to include multiple nozzle

manifolds which allowed flow rates to be changed quickly without removal

of nozzles from the system. A shed containing an instrumentation and

control room was added to house the computer and data logging equipment,

the pressure measurement standards and transducers, and the gas chromatograph and associated bottles of calibration gas. The remainder of

this section deals with the systems used to measure temperature,
CL

C ^ V ^ Vi 5 O ^ o t: CO

()5 OD liJ O < O

Figure 1 . Schematic diagram of the natural gas

test loop's major components
pressure, gas composition, and mass flow rate. These parameters form

the basic database from which orifice discharge coefficients are calculated. From these, we develop a method to calculate the uncertainty in the discharge coefficients for each test run.

A. General Description of the Experimental Apparatus and Test Flow Loop

A system for automated measurement of differential and absolute pressure, temperature, and gas composition forms the basis for the acquisition and storage system of the experimental database. The measurements

necessary and the systems used to make them are shown conceptually and

schematically in figures 2 and 3. Included in the measurement and data

storage system (fig. 3) is the provision for periodic calibration of the

differential and absolute pressure transducers . The general philosophy

used in the development of the measurement system provided by NBS was to

tie each measured parameter to the national standards of measurement

maintained by NBS (see fig. 2). Assessment of the magnitude of the

effects of each parameter on the total measurement uncertainty for the

orifice discharge coefficient was determined by a sensitivity analysis.

This analysis was used to determine the rigor with which each measured

parameter was compared with national standards.

B. Sensitivity Analysis of the Measurement System and Variation of the

Discharge Coefficient with Various Parameters

The effect of variation in the parameters upon which the orifice meter

discharge coefficient depends forms the basis for analysis of the

sensitivity and uncertainty of the measurement system. This analysis is

based on the mathematical expression relating the measured parameter

values to the discharge coefficient. This expression, which is derived

in Appendix C, is given by

Cd = ^(1 - p'yi^ / Nd^YF- (pAP)i/2 (1)

where C^j = orifice discharge coefficient,

m = mass flow rate through the orifice,

d = diameter of the orifice,

N = a constant whose value depends on the units of the

measured parameters (N = it/ljl for commensurate units) , p = density of the flowing fluid, natural gas in this

project,

Y = adiabatic expansion factor,

Fg = orifice thermal expansion factor,

AP = the differential pressure developed across the orifice

meter,

yS = d/D, the beta ratio, and

D = the diameter of the meter tube.
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system and parameters
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acquisition systems.

8
Each of these parameters is either measured directly or is the result of

observed values of two or more auxiliary parameters. The two diameter

values are measured directly; the remaining parameters are derived from

auxiliary observations, tabulated data, equations of state or models of

transport properties. Several of the auxiliary measurements require

calibration to make a direct tie to the U. S. national measurement

system as maintained by NBS . Discussions of the methods of calibration

and measurement traceability for each of these are given later in this

section. Here we discuss the sensitivity of the discharge coefficient

to variations in the parameters appearing explicitly in eq (1).

The effect on the discharge coefficient, C^j , of variations in a given

parameter are obtained in the usual manner by differentiating C^ with

respect to that parameter. The results were used to select the procedures and hardware for the data collection activities. The following

list gives the expressions for the relevant partial derivatives and the

corresponding expressions for the relative variation of the discharge

coefficient, AC^j/C^j , due to relative changes in each parameter.

Mass Flow Rate Variation

1 3Cd ^

3m

1

> •m

ACd . Am

Cd Cd

•m

The discharge coefficient varies linearly with the mass flow rate. As

will be discussed later, the uncertainty in the mass flow rate was determined from calibration procedures used to determine the discharge

coefficients for each nozzle of the set used as flow standards. The

magnitude of this variation/uncertainty in the measurement of the nozzle

discharge coefficients is taken as an upper limit target for the other

independent parameter measurements

.

Flowing Fluid Density Variation

1 3Cd ^

1 ACd ^

1 Ap

Cd dp 2p Cd 2 P

The density of natural gas is a computed parameter in this work.

Variation in its value depends on the accuracy of the equation of state

used for the computation, and on the accuracy of the observed parameters

which are the input data to the computation, i.e., pressure, temperature, and gas composition. The equation of state of Starling and

coworkers [2] is used in this work. A comparison of the calculated and

experimental values of pertinent parameters is given in Appendix D.

Although the estimate of the accuracy of the calculated properties

varies somewhat with pressure and temperature, differences between

experimental and calculated values do not exceed 0.1% over the pressure

and temperature region covered by the data. This level of accuracy

represents the current state of the art and is a limiting component in

the total error budget.
Orifice Expansion Factor Variation

The expansion factor, Y, depends on the ratio of the orifice differential pressure to the downstream static pressure (X), on the ^ ratio, and

on the real-gas isentroplc exponent (k) . Values of X are computed from

the pressure and differential pressure data, and values of k are computed using the equation of state described in section III. In

practice, the values of Y range from 1.0002 to 1.0005.

The uncertainty in Y is dominated by the uncertainties in X and k. If one assumes that the uncertainties in X and k are 10%, one finds an uncertainty in Y of approximately 0.08%. Because the uncertainties in X

and k are much less than 10%, we conclude that the uncertainty in Y is

much less than 0.1%. The uncertainty in Y may be ignored under these

circumstances and the contribution from this term dropped from the total

uncertainty statement.

Orifice Thermal Expansion Factor Variation

The effect of variations in the orifice thermal expansion factor, F^ , is

small due to the magnitude of the thermal expansion coefficient of the

orifice plate material, stainless steel. The thermal expansion of

stainless steel is of the order of 10" ^/"C, and for the temperatures

used in this work (15 to 40°C) , errors in the measured temperature and

calculated expansion coefficient are extremely small.

Differential Pressure Variation

aCj _ _ 1 . ACd _ _ 1 A(AP)

C. a(AP) 2AP Ch 2 (AP)

The variation of the discharge coefficient with the differential

pressure across the orifice meter is similar to that of the flowing

fluid density. However, this measurement has traditionally been one of

the more difficult to make with a small uncertainty. The approach taken

in this work was to make a large number of differential pressure

measurements using high quality, industrial-grade transducers, and to

calibrate them frequently against appropriate working standards. In

this way the uncertainty in this parameter is composed of a component

describing the performance of each transducer and a component describing

that of the working standard. The working standard was selected to

minimize the uncertainty in differential pressure at the elevated static

pressures at which these tests were run and to provide a practical means

of performing the calibration while maintaining its accuracy. Two sets

of differential pressure transducers were used: one to cover the

differential pressure range up to approximately 40 inches of water (1.4

psid or approximately 10,000 pascals), and the other the range from 40

to 150 inches of water (5.4 psid or 38,000 pascals). This was done to

reduce the uncertainty component in the transducer performance at the

lower differential pressures.

10
The absolute uncertainty in the measurement of the differential pressure

is nearly constant over the pressure range. Therefore, the relative

uncertainty increases as the differential pressure decreases. As a result, the minimum pressure used was approximately 10 inches of water

(0,4 psid or 2500 pascals), A realistic estimate of the uncertainty in

the differential pressure working standard is approximately 3 parts in

10,000. Taking this as the uncertainty in the differential pressure

value, one obtains approximate relative uncertainties for the highest

and lowest nominal differential pressures used in the testing procedures

of 0,03% (differential pressure of 150 inches of water) and 0,4%

(differential pressure of 10 inches of water)

.

Orifice and Meter Tube Diameter Variations

1 ad

2 1

) d Cd

2 Ad

Cd l-^' l-yS* d

aCn _ 2y9* 1 . ACh _ 2^* Ad

Cd ad 1-^" D Cd 1-)S\ D

The 2/(1-/3^) term in these relations amplifies the effects of uncertainty in the diameter measurements on that of the discharge coefficient.

For the range of beta ratios used in this work the magnitude of this

term ranges from 2 (for /3 = 0.1) to 3 (for yS = 0,75).

All diameter measurements were estimated to be made with an absolute

uncertainty of approximately 0.0002 inches (5 /xm) . The effects of this

uncertainty on the relative uncertainty in the discharge coefficients

are tabulated below for both the orifice and meter tube diameters. The

small diameter meter tubes are the most seriously affected by the

smaller beta ratio orifices.

Meter Tube Orifice Beta

AC^ n r AC,

(inches) (inches) (%) (%)

Diameter Diameter Ratio '- C^ -' "- C

6.0 0.63 0.11 6.3 X 10-2 8.1 X 10-7

6.0 1.25 0.21 3.2 X 10-2 1.3 X 10-5

6.0 3.00 0.50 1.4 X 10-2 4.4 X lO-"* 6.0 4.00 0.67 1.2 X 10-2 1.7 X 10-3

10.0 1.0 0.10 4.0 X 10-2 4.0 X 10-7

10.0 3.0 0.30 1.3 X 10-2 3.3 X 10-5

10.0 5.0 0.50 8.5 X 10-3 2.7 X 10- '• 10.0 7.5 0.75 7.8 X 10-3 1.9 X 10-3

11
C. Natural Gas Mass Flow Rate Measurement System and Uncertainty

1. General Description

The natural gas test loop at NGPL consisted of three major components:

(1) a water bath heater, (2) the orifice meter test section, and (3) the

critical nozzle manifold. The water bath heater had a capacity of one million BTU/hour to heat the gas entering the test loop. The purpose of

the heater was to raise the temperature of the gas above the hydrocarbon dew point in the throats of the critical Venturis. Otherwise

there could be substantial errors in the calculated mass flow rate due

to two-phase conditions in the nozzle throats. Estimates were made by

Starling and coworkers [7] of the conditions in the nozzle throat for

the onset of the two-phase region. These were related to the nozzle

plenum conditions to provide operational information. The capacity of

the heater was sufficient to raise the temperature of the gas to

approximately 60 "F at the higher flow rates during the cooler part of

the test schedule and to temperatures slightly in excess of 100 °F at

the lower flow rates. Data collection procedures were confined to the summer and fall of each year so that the temperature of the gas could be

maintained above 60 °F.

The configuration shown in figure 1 is that of the test loop as it

existed in the 1984 tests. During the spring of 1985 a second nozzle

manifold was added to allow most of the nozzles to be permanently

installed. The second nozzle manifold carried the smaller of the

nozzles and the larger, original manifold contained the largest nozzles.

The nozzles were identified by their throat diameters.

Each leg of the nozzle manifolds contained a platinum resistance

thermometer mounted in a thermometer well, a plenum pressure tap, and a flow straightener . The thermometer well was located upstream of the

flow straightener with the pressure tap located 1 to 3 pipe diameters

upstream of the nozzle inlet. Calculation of the mass flow rate of

natural gas through the system was based on the values of these temperatures and pressures for each operational nozzle of the manifold.

2. Natural Gas Mass Flow Rate Calculation and Nozzle Discharge

Coefficient Values

The mass flow rate of natural gas, m (lb/sec), through one of the

critical nozzles is calculated using

m = ^ " , (2)

(RT) 1/2

where P = inlet static pressure (psia)

,

A^ = nozzle throat area, (in^),

C* = critical flow factor for the flowing fluid,

Cj = nozzle discharge coefficient,

R = gas constant (ft-lb^ /lb-°R) , and

T = inlet gas temperature (°R).

12
All of the parameters in eq (2) except the discharge coefficient and

critical flow factor are measured or computed from measured parameters

or are thermodynamic constants. The discharge coefficient must be

determined through calibration of the nozzle. The nozzles were calibrated in air flows at CEESI. A report of these tests [8] characterizes

the dependence of the discharge coefficient upon the Reynolds number

based on plenum viscosity and throat diameter. The Reynolds number

value is computed using

48m (3)

where m = mass flow rate (lb/sec)

,

d = nozzle throat diameter (inches), and

H = natural gas absolute viscosity (Ib/ft-sec)

.

Computation of the viscosity was based on the nozzle inlet conditions

since no measurements were made in the throat.

Each of the nozzles was calibrated in air over the range of Reynolds

numbers for which they were expected to be used in the natural gas

tests. Since the nozzles were calibrated using a surrogate fluid having

physical properties different from those of natural gas, the pressures

at which the calibration data were taken were adjusted to encompass the

anticipated range of Reynolds numbers for the natural gas tests.

To calculate the nozzle discharge coefficients during the natural gas

tests, the following mathematical expression was used to characterize

the discharge coefficient calibration data of each nozzle:

= A + B Rd ^ ^ ^ . (4)

Values of the coefficients A and B were determined using the method of

least squares and are given in table 2 with the residual standard

deviations of the fits. The fitting procedures and the resulting

estimates were performed by CEESI.

Table 2. Coefficients of the nozzle discharge coefficient model

Nozzle A B Residual Nozzle Holder

Designation Std. Dev. (inches)

0.0950 0.99044 3.85 0.00033 2

0.1250 0.98270 8.29 0.00021 2

0.1880 0.99642 - 6.77 0.00032 2

0.2496 0.99347 - 6.666 0.00010 2

0.3750 0.99064 - 4.04 0.00024 2

0.5328 0.99940 - 9.77 0.00016 6

0.7537 0.99773 - 0.80 0.00025 6

1.0648 0.99352 10.36 0.00059 6

1.3751 0.98849 26.9 0.00041 6

1.9450 0.99547 - 9.9 0.00029 10

2.3300 0.99389 - 3.49 0.00044 10

13
The 0.1250 nozzle listed above was not part of the NGPL nozzle set. The

original nozzle, for which discharge coefficients are reported in [8],

exhibited unusual behavior in the calibration tests and was found

subsequently to have a defect sufficiently large to warrant manufacture

and testing of a second nozzle. This was done and the results of the

calibration tests are given in Appendix F.

The critical flow factor, C* , in eq (2) characterizes the real gas

effects of the fluid passing through the nozzle. The calculations of

Johnson [9] were used to obtain these values for the calibration fluid,

which was air. The approach used to calculate C* for the natural gas

mixtures used at Joliet is discussed in Section III.

3. Uncertainty in the Nozzle Discharge Coefficient Value

The uncertainty in the value of the nozzle discharge coefficient

calculated using eq (4) consists of the random variation in the discharge coefficient data upon which the coefficients A and B are based,

and the contributions of the various measured or inferred parameters

from which the discharge coefficients for a particular nozzle are calculated. The random variation may be estimated from the least

squares procedure used to assign values to A and B via the residual

standard deviation of the fit. Three standard deviations will be used

to attain a 99% confidence level in this estimate.

Estimates of the contribution to the uncertainty from the independent

variables on which C (nozzle) depends follow from a rearrangement of eq

(2):

Cd = m,/RT . (5)

PA^C*

Mass Flow Rate - The uncertainty in the mass flow rate measurement

depends upon which of the two CEESI flow measurement system was used in

the nozzle calibration. The primary system is based on a tank of

accurately known volume from which gas is expelled through the nozzle

under test for a measured time period. The secondary system consists of

nozzle sets calibrated in this way on the primary system. These are then used in parallel combinations as transfer standards for test nozzle

calibration at flow rates substantially above the maximtom of the primary

system. Consequently, the uncertainty of the secondary calibration

system is larger than that of the primary system since it must include

both primary system uncertainty and reproducibility of nozzle calibration using it. CEESI estimates the uncertainty of the primary system at

0.1% of the mass flow rate value and the secondary system has an uncer- tainty of 0.25% of the mass flow rate value. Uncertainties for both

mass flow rate determination systems will be considered to contribute

systematic error in the calibration of nozzle discharge coefficients.

Nozzles with diameters up to and including the 0.5328-inch nozzle were calibrated with both the primary and secondary systems and are assigned

the smaller uncertainty value. The larger nozzle calibrations used only

the secondary system.

14
Gas Constant - The uncertainty in the gas constant value is approximately 1 part in 30,000 or 0.003% [10]. This uncertainty is so much smaller

than that of the mass flow rate and the other parameters that its effect

is neglected in the analysis of error propagation.

Pressure - The relative uncertainty in the pressure value claimed by

CEESI is 0.04%.

Temperature - The level of uncertainty in the temperature value is

0.1 °F (0.055 °C) and is taken to be random. This gives a relative

uncertainty of 0.02%. (Temperature measurement is discussed fully in

sec. II. E.)

Nozzle Throat Area - Uncertainty in the nozzle throat area, or diameter,

does not contribute to the uncertainty in the nozzle discharge coefficient because the same diameter value is used during calibration and

subsequent use of the nozzle. As described later, however, there is an additional uncertainty in the measured mass flow rate through a single

nozzle when the temperature during test runs significantly differs from

that at the time of calibration. This additional term is added systematically to the error budget for the mass flow rate. It does not

appear in this error budget for the nozzle discharge coefficient, but is

discussed in a subsequent section related to total uncertainty of these

measurements

.

Critical Flow Factor for Air - The calibration of the nozzles at CEESI

used air as the flowing fluid. The uncertainty in the critical flow

factor for air will be estimated from comments made by Johnson [8]

concerning the level of agreement between his calculation of physical

parameters for air and tabulated thermodynamic properties (Hilsenrath

[11]) for air.

The critical flow factor is defined by the following equation:

C* = Gt (RTp)i/VPp and

Gt = PtUt .

where G^ = mass flow rate per unit area,

T = plenum temperature,

P = plenum pressure,

Pt = density in the nozzle throat, and

U^ = velocity in the nozzle throat.

Johnson calculated the gas density using an equation of state to compute

its compressibility, and then computed the density with the compressibility to carry the real gas effects. His stated level of agreement

for compressibility values with reference [11] is 0.1 percent as a worst

case estimate.

Johnson's calculation of gas velocity in the throat was dependent upon

values of the enthalpy obtained from tabulated values in [11]. It is

assumed that the interpolation methods used by Johnson did not significantly increase uncertainty in the enthalpy values used for velocity

15
computation. Therefore, the enthalpy uncertainty stated in [11] of

approximately 1 or 2 x 10"^ is the primary uncertainty contribution to

the computed throat velocity and is considerably below that of the

compressibility. The uncertainty in C* is the sum of the uncertainties

in throat velocity and density, or 0.12%.

The total error budget for the mass flow rate through a single nozzle,

to be developed in subsequent sections of this report, includes the

uncertainty in the nozzle discharge coefficient and the uncertainty in

C* for natural gas. For natural gas we develop numerical estimates of

the uncertainty in C* using the equation of state. Thus, the total

uncertainty in the mass flow rate includes the uncertainty in C* for air

(from the nozzle calibrations), estimated at 0.12%, and the uncertainty

in C* for natural gas (from the test runs) , estimated numerically.

Combined Uncertainty in Nozzle Discharge Coefficients

Calculation of the total relative uncertainty in percent in the

discharge coefficient for each nozzle requires that the random

uncertainty from the fit used to determine A and B be combined with the

random and systematic uncertainties in the values of C^ calculated from

eq (5) . The uncertainties in the fit and in the values of C^ are combined additively but in the calculation of the latter the random

contributions are combined in quadrature and the systematic components

additively. Denoting the resultant total uncertainty by s , one has

(nozzle) = 3s

Cdf

2 2 2 + (3sp)^ + 1/4 (St)

1/2 + s. + s

where s Cdf = residual standard deviation of the fit for Cd ' divided by C^ , expressed in percent,

Sp = the relative uncertainty in the nozzle pressure

value in percent,

s^ = the relative uncertainty in the nozzle mass flow

rate value in percent,

s^ = the relative uncertainty in the temperature in

percent,

Sq = the relative uncertainty in the critical flow factor

for air in percent.

For nozzles that were calibrated using CEESI's primary and secondary

flow rate calibration systems, the total relative uncertainty in the

discharge coefficient is based upon the primary system:

16
s (nozzle) =

f •\

3s

Cdf

V. J

^ + (0.04)^ + 1/4(0.02)^ 1/2 + 0.1 + 0, 12

f -v 3s

Cdf

2 -4 + 17 X 10 1/2 -H 0. 22

For nozzles that were calibrated using CEESI's secondary system only,

the total relative uncertainty in the discharge coefficient is computed

using

s (nozzle) =

*^d 3s

Cdf

V. J

2 + (0.04)2 ^ 1/4(0.02)2 1/2 + 0,25 + 0. 12

f "v 3s

Cdf

2 -4 + 17 X 10 1/2 + 0.37

The six smallest nozzles, i.e., those having throat diameters of 0.5328

inches and smaller, were calibrated using the CEESI primary flow rate

measurement system. The remainder used the secondary system only and

are assigned the larger relative uncertainty.

The uncertainty in the mass flow rate of natural gas through a single

critical nozzle depends on the uncertainties in the nozzle discharge

coefficients determined at CEESI. A conservative estimate of this

uncertainty is obtained in Section IV by treating s _ as a random

Cdf

uncertainty and the remaining contributions as a systematic uncertainty.

17
D. Static and Differential Pressure Measurement Systems and Standards

1. Pressure Measurement Requirements and Units

Measurement of the static and differential pressures at each orifice

meter and nozzle was one of the primary measurements made during this

project. The criteria used in selecting the measurement methods were:

• The method must significantly reduce or eliminate the need for

manual transcription of data, and therefore, the error rate

associated with it, and be compatible with the automated data

acquisition and storage techniques used in the project,

• The method must incorporate working standards of pressure for

in-situ calibration of static and differential pressure measurement devices

• The method must be capable of an accuracy consistent with the level

of uncertainty in the measurement of the mass flow rate. This is

determined by the uncertainty in the calibration of the critical

nozzles

• The capability to maintain this accuracy level between successive

pressure calibrations must be retained.

Throughout this report several sets of pressure units are used. It is

common industrial practice in the United States to use inches of water

in describing differential pressure measurement and pounds per square

inch for absolute, gauge, or differential pressures. The abbreviations

psia, psig, and psid will be used for these, respectively. To satisfy a broader community, the SI system (pressure units of pascals) is generally included parenthetically. For convenience in the remainder of this

document the following conversion constants between the pressure units

are given. These are generally recognized and are contained in American

National Standard Z210. 1-1976.

1 pascal = 1 newton/meter^

1 pound force/inch^ = 6894.76 pascals

1 inch of water (60 °F, 15.55 °C) = 249.08 pascals

1 inch of water (39.2 °F, 4 °C) = 248.84 pascals

2. Differential Pressure Transducers

Measurements of the differential pressure across the orifice meter were made using industrial quality, diaphragm type, differential pressure

transducers. Voltage output from all transducers were measured using a data logger having a 5 1/2-digit resolution, i.e., 1 part in 200,000.

This resolution is much below any other source of error and is neglected

in the uncertainty analysis. The pressure transduction instruments were selected by the API orifice database project committee and were com18
patible with the electronic data acquisition and storage system used in

the project. Several sets of these transducers were used during the course of the project. The basis for transducers changes is discussed

later in this section. Provision for frequent calibration of these

devices was designed into the data acquisition system to provide the

capability to attain sufficiently accurate characterization of the

transducer response and maintain traceability with the U.S. national

measurement system.

Two operating ranges were selected to cover the range of orifice meter

flow rates. The maximum flow rates corresponded to differential

pressures of 150 to 250 inches of water (5.5 to 9.2 psid, 37 to 63

kilopascals) . To achieve redundancy in the measurement system, two

transducers for each of the two ranges were used. The low range

differential pressure transducers had a span of approximately 40 inches

of water. Three sets of high range transducers were used. The first

two sets were used in the test data collected in 1984; one had a range

of 200 inches of water and the other 150 inches of water. During 1985 a third set of both high and low range transducers was used. In that case

the largest differential pressures measured were approximately 250

inches of water. The upper end of the lower range was maintained near

40 inches of water.

Figure 4 shows the interconnection of the differential pressure

transducers, the orifice meter, and the differential pressure calibration apparatus. The latter is discussed in more detail below. It

should be noted that the connections of the differential pressure

transducers to the orifice meter taps were made on the top set of tap

holes only. These were located at the 12 o'clock position. The

connection location shown in figure 4 facilitates the presentation but

does not reflect the actual connection configuration. Each of the

transducers was isolated from the remainder of the transducer manifold

with seven-valve manifolds which allowed any of the transducers to be

connected to the atmosphere, the pressure developed in the orifice

meter, or the pressure developed in the calibration portion of the

transducer manifold. In normal operation the full range of differential

pressures was admitted to each transducer, both for pressure measure- ments during test runs and for calibration procedures. Each transducer

was fitted with a mechanical stop to arrest the motion of its diaphragm

before damage occurred.

The 40- inch transducers had their operating span set to 40 inches of

water for use in the lower differential pressure region. The original

intent was to limit the low range transducers to 20 inches of water, but

the transducers operated sufficiently well up to 40 inches that the low

range was extended to 40 inches of water or below. The first set of

transducers designated as 200 inches were actually transducers whose

upper limit was 750 inches of water and had been re-spanned to 200

inches of water. These transducers were used until late August of the

1984 operating season. Because of a consistent difference between the

upper range transducers and the lower range transducers in the region of

response overlap, a series of operational tests of the transducers was performed. These tests are described fully in Appendix B and demonstrated that the procedures used immediately after the calibration of

19
the transducers induced significant shifts of the zero differential

pressure response in the high range transducers only. The procedures

inducing this effect were those necessary to switch the transducer

connections from the calibration side of the manifold to that of orifice

meter.

Prior to August, 1984, calibration procedures were performed at a static

or base pressure of 600 psig. Following the calibration, the transducers were valved onto the orifice meter side of the manifold which was operating in the pressure range 480 to 750 psig. In switching the

valves between the two sides of the manifold, differential pressure

excursions much larger than the range of the transducers were presented

to the transducers. These excursions caused changes in the zero differential pressure response of approximately 0.5 inches of water in

the high range transducers only. This appeared to be a constant shift

in the response until the transducers were overpressured again. During

the course of these diagnostic tests the low range transducers were

connected to the manifold in the same way as the high range transducers

and were subjected to the same overpressurization regimes. The maximum

shift in the zero differential response appeared to be less than 0.03

inches of water for one and 0.01 for the other of these transducers.

Because of this difficulty, the high range transducers and one of the

low range transducers were replaced. The high range transducers were replaced with transducers having a maximum span of approximately 175

inches of water. The replacement of the low range transducer was not

required, but was done anyway. The performance of the second set of

high range transducers was improved over the initial set, although the

upper flow rates at which orifice meters could be tested was reduced by

approximately 25%. As a result of these circumstances, the orifice

meter test points were rerun. In the results database of this project,

test points above 40 inches of water are excluded because of the poor

performance of the high range transducers during this period. However,

the points below 40 inches of water remain as part of the database since

these transducers were found to be operating in an acceptable manner.

In addition to the change of transducers, a change in calibration

procedures was made. Rather than calibrate the differential pressure

transducers at 600 psig, the base pressure was adjusted to be reasonably

close to that of the test loop at the time of calibration. This

pressure value was obtained from the Joliet station operations personnel

shortly before the calibration procedures began.

Before the 1985 operating season was begun, a new set of high and low

range transducers were obtained and mounted. These were used throughout

the 1985 testing schedule and performed well.

20
0)

CO O

Figure 4. Differential pressure transducer manifold

schematic diagram.

21
Calibration of the transducers was performed over the full operating

pressure range using the small pressurization pump shown at the lower

right in figure 4. These procedures were performed with nitrogen as the

calibration fluid. The working pressure standard for differential

pressure was a Model DDR- 6000 quartz bourdon tube differential pressure

transducer manufactured by the Ruska Instrument Corporation [12] . This was connected to the transducer manifold through a three valve manifold.

The DDR 6000 was filled only with nitrogen and never with natural gas

since it was not of an explosion proof design.

This was done to eliminate the hazard of explosion in the control room

area of the instrumentation shed where it was located. Purging of the

manifold with nitrogen was done with the appropriate venting valves

located on each transducer. The differential and static pressure

transducer manifolds were maintained at the operating base pressure

levels when not in use to minimize adverse effects due to pressurization/depressurization cycling.

3. Static Pressure Transducers

Static pressure measurements were made using industrial grade, diaphragm-type transducers. Pressure measurements are required at several

locations in the measurement system, i.e., the orifice meter and each

critical flow nozzle's plenum. Five static pressure transducers were used for these measurements. An additional set of four transducers, of

somewhat lesser quality, were used to measure the downstream pressure of

each nozzle in the main manifold to give a measure of whether the nozzle

had achieved conditions necessary for critical flow. Details of the

interconnecting piping for both the differential and static pressure

transducers are given in Appendix A with photographs of the transducer

mounting hardware.

4. Working Pressure Standards

Incorporation of working standards into the measurement system was done

using two types of devices. The working pressure standard for the

static pressure measurements was a model HK-1000 ball -type deadweight

pressure gauge manufactured by Ametek [12]. This device was used to

develop known pressures from 400 to 800 psig which were applied to the

static pressure transducers during calibration procedures. In all of

the calibration procedures the working fluid was nitrogen obtained from

bottles kept in the transducer room of the instrument shed.

The deadweight tester was calibrated by the NBS Pressure Standards Group

before it was placed in service. The Ruska DDR-6000 was calibrated by

the manufacturer before delivery to NBS and was calibrated several times

against a high pressure mercury manometer [13] at the NBS Boulder

Laboratories before it was placed in service at the Joliet test site.

It was calibrated again by the NBS Pressure Standards Group after the

testing program was completed.

22
5. Static Pressure Working Standard

The calibration of the deadweight tester produced an effective area for

the ball and an uncertainty in this value over the calibration pressure

range of 60 to 550 psia. A small pressure dependence of the ball area

was indicated by the presence of a small apparent residual force in

addition to that generated by the weight stack itself. Adjustment for

this effect is afforded by assignment of a non-zero value as the tare

force of the deadweight tester. Mass values were assigned to the

weights, the ball, and the weight carrier of the deadweight tester.

These values and the area of the ball, the local acceleration of

gravity, the tare force, and the atmospheric parameters (barometric

pressure, relative humidity, and air temperature) were used to compute

the pressure developed by the deadweight tester during static pressure

transducer calibration.

Computation of the pressure developed by the deadweight tester involved

computation of the density of air, the assigned area of the ball, the

tare force, and the total mass of the weight stack. Since pressure is

defined as force per unit area, the force exerted on the deadweight

tester's ball must be calculated for each stack of weights used in

developing a particular pressure. The apparent mass value of the weight

stack is computed using eq (6), which accounts for the buoyant force of

the atmosphere on the objects exerting a force on the ball. The

apparent mass is the difference between the force of gravity pulling the

weight stack toward the center of the earth and the buoyant force of the

atmosphere directed in the opposite direction.

M, = M^ (1 - pjd^), (6)

where M^ = true mass of the combined weight stack,

Mg = apparent mass,

d^ = density of the weight material, and

Pg = density of the air surrounding the weight.

The weights were made of stainless steel having an assigned density of

7.8 g/cm^ . However, the materials making up the weight stack and

contributing to the force on the ball were not only the stainless steel

weights, but also the weight carrier and the ball itself. The true mass

values, weight designations and nominal pressure produced by each

weight, when placed on the deadweight tester, are given in table 3.

23
Table 3. Pressure gauge weight mass values, maker number 76837

True Mass Value

(Ibm)

3.974990

4.416426

4.416539

4.416564

4.416808

4.416791

4.417021

4.416643

4.416521

2.208379

0.883407

0.883368

0.441675

0.220829

0.088337

0.088335

0.044160

0.440740

0.000966

(assumed density of stainless steel is 7.8 g/cm^

)

Once the apparent mass of the weight stack had been computed the

pressure value was computed using

Nominal Weight

Pressure Designation

90 psi # 1 100 psi # 2

II # 3

It # 4

II # 5

II # 6

II # 7

II # 8

II # 9 50 psi # 10

20 psi # 11

20 psi # 12

10 psi # 13

5 psi # 14

2 psi # 15

2 psi # 16

1 psi # 17

Weight carrier

Ceramic ball

P = (M^g - W) / Ab[l - a(T - 23)], (7)

where P

g

W =

Ab =

a =

T =

pressure,

local acceleration of gravity calculated for the

Joliet test site (980.2429 cm/sec^ ) [14],

tare force determined in calibration of the

instrument,

area of the ball,

area thermal expansion coefficient for the ceramic

ball/stainless nozzle combination, and

temperature in degrees Celsius.

Equation (7) includes a correction for the small thermal expansion of

the stainless steel/ceramic ball combination. The reference temperature

of 23 "C is that at which the testers were calibrated. Introduction of

the appropriate units for each of the quantities in eq (7) results in eq

(8) , which was used to compute the pressure developed by the deadweight

tester. Equation (8) gives the pressure in the SI units of pascals

(newt.ons/meter^ ) . The conversion factor 1.450377 x 10"^ psi/pascal is

used to express the pressure value in customary units of psi.

24
[0.4535924 (kg/lb) x M^ (lb) x 9.802429 (m/sec^ )

] - W

P = . (8)

Aj, (m2) {1 + 0.0000167 [T(°C) - 23]}

6. Uncertainty in the Static Pressure Working Standard

The statement of uncertainty in one of the working pressure standards is

composed of the following components:

• the uncertainty in the area assigned to the ball,

• the uncertainty in the buoyancy correction for the weight

stack,

• the uncertainty in the mass value of the weight stack,

• the uncertainty in the tare force

,

• the uncertainty in the value of the acceleration of

gravity, and

• the uncertainty in the values of the thermal expansion

coefficients for the ceramic ball and the stainless steel

nozzle/ball retainer.

The uncertainty in the area assigned to the ball and that assigned to

the tare force are obtained from calibration of the deadweight tester

against the national working pressure standard by the NBS Pressure &

Temperature Division (Calibration Report P-7959) . The effective area assigned to the ball was 2.850007 x 10"^ m^ with a relative random

uncertainty of 22.9 parts per million. The tare force value assigned

was 6.779506 x 10" •^ newtons with an uncertainty of 1.8315 x 10"^

newtons . The relative systematic uncertainty in the national pressure

standard used to assign these values is reflected in the uncertainty in

the effective area value and is 54 parts per million of the effective

area.

The uncertainty in the buoyancy correction for the weight stack is due

to the effects of uncertainty in the density of the air and the weights.

The relative uncertainty in the density of the weights is taken to be

1%. As is the relative uncertainty in the density of air. A discussion

of the effect of uncertainty in computed air density values on deadweight testers is given in reference [1]. Computation of air density

values used the formulation of Jones [10]. Taking partial derivatives

of eq (7) and approximating factors of Mag/(Mag-W) by unity, one obtains

1 aP -1 AP -p, Lp,

and

P dp, d„-p, P d^-p,

1 3P pa 1 . AP p. Adw

P dd^ d^-pg d„ P d„-p3 d„

25
These expressions give the relative uncertainties in the pressure due to

the uncertainty in the buoyancy correction in eq (7) . Substitution of

nominal values for the density of air (0.00117 g/cm^ ) and stainless

steel (7.8 g/cm^ ) gives values for the relative magnitudes of these

effects of approximately 2 parts per million each. The combined effect

is 4 ppm for relative uncertainty due to air buoyancy effects. This

uncertainty component is taken to be random in effect.

The uncertainty in the assignment of the mass values for the stainless

steel weights and the weight carrier is 15 micropounds at the 99%

confidence level. The uncertainty in the mass assigned to the ball is

less than 1 micropound. The total relative uncertainty in the mass of

the weight stack combinations used in calibration procedures between

pressures of 400 to 800 psia is 3 to 4 parts per million and is taken to

be systematic.

The tare force assigned was 6.779506 x 10" ^ newtons with an uncertainty

of 1.8315 X 10"^ newtons. The relative uncertainty in this quantity is

normalized by the total force exerted on the effective area of the

ball/nozzle combination. For the pressure range 450 to 750 psia, the

force ranges from approximately 88 to 147 newtons. Therefore, the

relative uncertainty in the tare force ranges from 12 to 21 parts per

million. The tare force uncertainty is taken as a random contribution

in the pressure uncertainty since it is derived from the fitting

procedures used in its determination.

The uncertainty in the local acceleration of gravity at the Joliet, IL

County Court House is estimated [14] to be 0.002 cm/sec^ relative to a value of 980.2429 cm/sec^. We arbitrarily double the magnitude of this

uncertainty estimate to account for changes in longitude, latitude and

elevation of the test site relative to the court house. The relative

uncertainty is therefore assigned to be 4 parts per million and is taken

to be systematic.

The effects of uncertainty in the thermal expansion coefficients of the

steel nozzle holding the ball and of the ball itself are estimated to be

approximately 10% of the value of each [15]. Since operation of the

deadweight testers was in the 20 to 25 °C range due to air conditioning

of the transducer room, the magnitude of this effect on the uncertainty

in the pressure is 3 to 5 parts per million [see eq (8)]. This con- tribution is taken to be systematic.

A statement of the total relative uncertainty in the deadweight tester

pressure is obtained by combining the random contributions in quadrature

and the systematic contributions additively. A summary of the various

contributions is given in table 4. For those contributions which are dependent on the pressure range, the component of largest magnitude is

used in the summation of error components

.

26
Table 4. Relative uncertainty in the static

pressure working standard

Random Systematic

(ppm) (ppm)

Ball area assignment 23 54

Tare force 12 - 21

Buoyancy correction 4

Weight stack mass values 4

Acceleration of gravity 4

Ball/Nozzle thermal expansion coeff , 5 Component Summations 26-31 67

Total Estimated Uncertainty -- 93 - 98 parts per million

The total estimated relative uncertainty in the pressure developed by

the deadweight tester for calibration of the static pressure transducers

is taken to be 98 parts per million. The total estimated absolute

uncertainty ranges from 0.045 at 450 psia to 0.074 at 750 psia.

7. Barometric Pressure Measurement and Its Uncertainty

The static pressure transducers were referenced to atmospheric pressure

and calibrated in that manner. Computation of absolute pressure values

for the nozzles and the orifice meter requires a measured value of the

barometric pressure be added to the values obtained from the static

pressure transducers. A mercury barometer was used at the Joliet

station for this purpose. Its location, physically outside the test

loop, required the use of a transfer device for measurement of the

barometric pressure for the test runs. The mercury barometer was used

to determine any offset in reading of the aneroid barometer used as the

transfer device. Therefore, the uncertainty in the barometric pressure

is the sum of that of the mercury and aneroid barometers. The uncer- tainty in the mercury barometer is taken to be 0.5 millimeters of

mercury and is composed primarily of operator reading variability. The

aneroid barometer was a small device which had a readability of 0.05

inches of mercury (1.3 millimeters of mercury). The combined uncertainty of these is 1.8 millimeters of mercury or 0.034 psia.

8. Uncertainty in the Differential Pressure Working Standard

The uncertainty in the differential pressure working standard is derived

from its calibration. As mentioned earlier, several of these have been

performed over the lifetime of this project. The initial calibrations

were done at the NBS Boulder Laboratories using several types of

instruments as the standard for the DDR- 6000 used at Joliet. These were

• a piston gauge for setting elevated base pressures and for

calibrating at an atmospheric base pressure,

• a high pressure mercury manometer [13], and

27
• a second DDR- 6000 owned by NBS which had been calibrated

previously using the dual float piston gauge method and the

high pressure manometer.

Several base pressures were used in the calibration measurements. These

included atmospheric pressure, 500 psia, and 600 psia. A piston gauge

was used for calibration of the DDR-6000 at atmospheric pressure. The

differential pressures ranged from 10 to 200 inches of water (2500 to

50,000 pascals) which was approximately one half the range of the

instrument. The calibration procedures performed at NBS Boulder

generally consisted of 16 or more differential pressure points at a fixed base pressure. Table 5 lists the results of these calibration

measurements on the DDR-6000 s/n 32723.

Table 5. Calibration results for the differential

pressure working standard

Date Base Calibrating DDR-6000 Re sidual Standard

Pressure Instrument Slope Deviation

(psig) (psid/volt) (pa) (psid) (in. H2

Jan. 1984* 600 DDR-6000 (NBS) 1.45035 5.2 0.00076 0.021

Jan. 1985* 14 Piston Gauge 1.45013 0.7 0.00001 0.003

Jan. 1985* 500 Manometer 1.45016 9.9 0.00144 0.040

Jan. 1985* 600 Manometer 1.44997 6.2 0.00090 0.025

June 1986! 600 Dual Pist. Gauge 1.45038 5.0 0.00073 0.020

* - Calibration performed at the NBS Boulder Laboratories

! - Calibration performed by the NBS Pressure Standards Group,

Calibration Report P-8053

The atmospheric pressure calibration of the instrument shows that its

slope is linear to approximately 30 parts per million at the 99%

confidence level (three standard deviations). This method of calibration is one that minimizes the uncertainty in the standards used in the

calibration since only the uncertainty associated with the piston gauge

itself applies. This piston gauge was calibrated against those used as U.S. national 'standards and has an uncertainty of 54 parts per million.

This 54 parts per million is mostly systematic with a small random

component of 4 to 5 parts per million. This random component con- tributes variability to the calibration of the DDR-6000 and is only a small part of the 30 parts per million seen in the variation of its

slope. The remainder of the variability must be attributed to the

inherent variability of the instrument.

The calibrations of the differential pressure working standard performed

at the NBS Boulder Laboratories were done using instruments other than

national standards to give an indication of the stability of the

instrument over the period of the project. The value for the slope used

for computation of the differential pressures developed during calibra28
tion of the transducers is that obtained by the NBS Pressure Standards

Group. This group used the dual float piston gauge method and had the

direct involvement of instruments used as U.S. national standards. The

uncertainty in the assignment of the slope to the DDR-6000 is composed

of the uncertainty of the standards used in the calibration and the

variability of the instrtoment during the calibrations. The assignment

of the slope was the result of a least squares fit to 30 calibration

points taken over a time of several days. Three standard deviations of

the slope value is 0.00012 psid/volt or 0.008% in relative terms. This

variability added to the 100 parts per million (0.01%) uncertainty in

the standards gives a total uncertainty in the DDR-6000 of 0.018% of the

differential pressure value. Application of this relative uncertainty

to the pressure values used during calibration of the transducers gives

the following absolute uncertainties:

Calibrating

Diff. Pressure

(inches of water) (psi)

Uncertainty

(inches of water) (psi)

20

35

150

250

0.722

1.263

5.414

9.023

0.0036 0.0001

0.0063 0.0002

0.027 0.0010

0.045 0.0016

9. Pressure Transducer Calibration Procedures

The static and differential pressure transducers were calibrated in

separate procedures using their respective working pressure standards.

The order of the calibrating procedures was (1) low range differential

pressure transducers, (2) high range differential pressure transducers,

and (3) static pressure transducers. These procedures were performed

before each day's data collection procedures and formed an integral

portion of the database structures for the project.

a. Differential Pressure Transducer Calibration Procedures

Calibration of the differential pressure transducers begins by opening

the valves connecting the transducers to the calibration gas manifold

and isolating them from the natural gas plumbing. The calibration gas

manifold includes a high-pressure, hand-operated pump, the differential

pressure transducers and the differential pressure working standard.

The calibration manifold is filled with nitrogen from a regulated

source to a pressure of either 600 psig or to a value closely approximating that of the pipeline operating pressure as determined from

the pipeline operating conditions of the Joliet station. Differential

pressures are obtained by use of the hand pump to compress the gas in

the high pressure side of the manifold. The low and high range transdu- cers were calibrated using separate pressurization schedules.

29
The pressurization schedules were changed over the course of the testing

program to accommodate changes in transducers and transducer ranges (see

sec. II.D.13 for specific dates). The number of calibration points in

the schedules was changed somewhat but not substantially. Either 9 or

10 point calibration schedules were used for the low range transducers

with 11, 12 or 13 point schedules used for the high range transducers.

The upper limits of the schedules were also adjusted to fit the various

transducer ranges and the upper flow rate ranges desired for each

orifice meter. At the beginning of the project the low range transducers were used only below approximately 20 to 25 inches of water and were calibrated through a 30 inch of water range. The calibration schedule

was changed later in the 1984 season to 35 to 40 inches of water

allowing the upper limit of measurement to be near 35 inches of water.

All of the low range transducers were out-of-range above 41 to 42 inches

of water. At that point the transducer's diaphragm was restrained by a stop. Table 6 gives a listing of the low and high range transducer

schedules. This table was taken from the information displayed for the

operator by the data acquisition system. The target voltages for the

DDR-6000 were displayed for each calibration point along with the

nominal pressure value.

Table 6. Di fferential pressure transducer calibration s chedules

Low Range - High R.ange

Target Nominal Target Nominal

Voltage Pressure Level Voltage Pressure Level

0.00 inches of water 0.00 inches of water

0.30 12 II II 0.50 20

0.50 20 II 1.00 40

0.70 28 11 1.49 60

0.90 36 II 2.24 90

0.80 32 II 2.98 120

0.60 24 II 4.23 170

0.40 16 II 5.97 240

0.20 8

II 4.98 200

0.00 II 3.73

2.49

1.24

0.75

0.00

150

100

50

30

II 1

Calibration observations of either set of differential pressure transducers began with an observation of the zero differential pressure of the

DDR-6000. This was done with its crossover valves open. Several

observations of this voltage were made and the mean value stored. The

first nonzero differential pressure observation point of the schedule

was then set by the NGPL operator using the hand pump to set the DDR6000 voltage to a value within a few percent of the target value. When

30
the DDR-6000 voltage had stabilized, five successive readings of the

transducer voltages and of the DDR-6000 voltage were made, the means

calculated, and the values stored by the data acquisition system. The

last observation of either schedule was of the zero differential

pressure response voltages. These were observed with the high and low

sides of each transducer connected together through the crossover valves

fitted to each transducer manifold. Following this observation the

crossover valves were closed and the transducers were switched over to

the natural gas portion of the manifold for orifice meter measurement

procedures. A typical set of observations for both sets of differential

pressure transducers is shown in table 7. The differential pressure of

the calibration manifold as measured by the DDR-6000 working pressure

standard is given in units of psid and nominally in inches of water.

The transducer voltage values listed are the mean values.

Table 7. Differential pressure transducer calibration data

for August 9, 1985 at a static pressure of 580 psig

Low range transducer calibration data

Obs. Time DDR -6000 HW-003 HW-004

No. PreiBsure Voltage Voltage

(psid) (In. H20) (Volts) (Volts)

1 06:57:59 0.4381 12.140 4.41022 4.43062

2 06:59:26 0.7390 20.476 6.07872 6.09578

3 07:00:42 1.0307 28.558 7.68574 7.71160

4 07:01:45 1.3313 36.887 9.35030 9.37590

5 07:02:38 1.1876 32.906 8.55844 8.58190

6 07:03:45 0.8966 24.842 6.94800 6.97044

7 07:05:03 0.6028 16.703 5.32308 5.34382

8 07:06:15 0.3175 8.797 3.74336 3.76008

9 07:07:51 -0.0012 -0.033 1.98302 1.99596

High range transducer calibration data

Obs. Time DDR--6000 HW-OOl HW-002

No. Pressure Voltage Voltage

(psid) (In. H20) (Volts) (Volts)

1 07 10:45 0.7373 20 429 2.65206 2.65132

2 07 12:01 1.4598 40 448 3.29476 3.29414

3 07 12:41 2.1640 59 958 3.92008 3.91862

4 07 13:42 3.2775 90 809 4.90342 4.90496

5 07 14:28 4.3324 120 039 5.84006 5.84122

6 07 15:09 6.1320 169 900 7.43586 7.43792

7 07 15:58 8.6536 239 764 9.67372 9.66958

8 07 17:20 7.2130 199 851 8.38762 8.39286

9 07 18:33 5.3951 149 481 6.77700 6.78084

10 07 19:23 3.6864 102 138 5.26128 5.26234

11 07 :20:12 1.8199 50 424 3.60878 3.61062

12 07 :20:44 1.1257 31 190 2.99200 2.99500

13 07 :22:02 0.0004 010 1.99990 1.99734

31
b. Static Pressure Transducer Calibration Procedures

Calibration of the static pressure transducers was done over a pressure

range that exceeded the test loop operating pressure range. Initially

the calibration range was 400 to 700 psig; however, as the data collection phase of the project progressed, test loop operating pressures

exceeded 700 psig. To harmonize the operation and calibration pressure

ranges of the transducers, another point was added to the calibration

schedule at 800 psig. Daily calibration procedures were performed on

the five static pressure transducers used to measure the orifice static

pressure and the four nozzle plenum pressures. The four transducers

used to measure the downstream static pressure were calibrated shortly

before their installation but not again. This was done because these

measurements were non-critical for data reduction purposes. Although

the pressure ratio across the critical Venturis was an operational

surveillance measurement. It was not sensitive to errors in the

downstream pressure of a few percent.

The calibration schedule consisted of a sequence of pressures developed

by the deadweight tester and applied to the five static pressure

transducers beginning at 400 psig. The calibration pressures were increased in steps of 100 psig to the upper limit and then decreased

similarly until the last pressure was nominally that of the second of

the calibration steps; i.e., 400, 500, 600, 700, 800, 700, 600, 500

psig. At the beginning of the calibration procedure the barometric

pressure was observed using an aneroid barometer. The units of this

observation were inches of mercury. This value was converted to psia

and added to the pressures calculated for the deadweight tester.

Observations of the response voltages of the transducers were made by

the data acquisition system after the operator was satisfied that the

deadweight tester pressure had stabilized. This judgment was made by

observation of the voltage from one of the transducers shown on the data

logger display. At the operator's command, the data acquisition system

took five successive observations of this set of voltages, computed and

stored the means in a temporary disk file for later storage in the

appropriate database. Table 8 lists the results of a typical calibration procedure.

Table 8. Calibration data for the static pressure

transducers for August 9, 1985

Time Barometric ~- Deadweight Tester -- Total

Pressure Temp. Mass Pressure Pressure

(mm Hg) (psia) (°C) (lb) (psig) (psia)

07:25:47 750.39 14.51 22.77 17.66622 399.913 414.302

07:26:55 750.39 14.51 22.77 22.08279 499.891 514.242

3 07 27 39 750 39 14 51 22 77 26 49982 599 880 614 192

4 07 28 16 750 39 14 51 22 77 30 91685 699 869 714 142

5 07 29 10 750 39 14 51 22 77 35 33348 799 849 814 083

6 07 29 50 750 39 14 51 22 77 30 91685 699 869 714 142

7 07 30 40 750 39 14 51 22 77 26 49982 599 880 614 192

07:31:27 750.39 14.51 22.77 22.08279 499.891 514.242

32
Table 8. Calibration data for the static pressure

transducers for August 9, 1985 mean voltage

observations -- Continued

s/n 541529 s/n 541528 s/n 541530 s/n 541532 s/n 541533

(volts) (volts) (volts) (volts) (volts)

1 5.10530 5.19300 5.17212 5.17586 5.19856

2 5.89350 5.98574 5.96144 5.96800 5.99028

3 6.68946 6.78260 6.75612 6.76392 6.78780

4 7.48742 7.57816 7.55190 7.56182 7.58358

5 8.28862 8.37450 8.35012 8.36166 8.37990

6 7.49030 7.58196 7.55552 7.56610 7.58718

7 6.69326 6.78742 6.76104 6.76998 6.79204

8 5.89818 5.99190 5.96726 5.97466 5.99542

Static Pressure Transducer Location Key

Serial Number Location

541529

541528

541530

541532

541533

Orifice Static Pressure

Nozzle 1 Plenum Pressure

II 2 " "

II O II It

II A II II

10. Transducer Response Functions and Coefficient Values

Upon completion of the observation sequences, the sets of response

values for each transducer were combined with the corresponding pressure

values to form data pairs for use in a least squares fitting procedure.

Polynomial models having the transducer voltage response as the independent variable and the differential or static pressure as the dependent

variable were used to interpolate through the range of the calibration

data. Polynomials having degrees up to and including three in the

voltage were fit to the calibrating pressure values for each transducer.

The degree giving the best fit was selected for each, based on the

reduction in the residual standard deviation relative to fits of lesser

degree. In this way the degree of the polynomial used to represent the

response of each transducer was determined. These procedures were

conducted for the transducers when they were installed. All of the low

range differential pressure transducer response functions were linear.

The high range differential pressure transducer response functions were

either quadratic or cubic depending on which of the three sets was in

service. A single set of static pressure transducers was used throughout both seasons of data collection, and their response functions were quadratic in voltage.

As an example of the values of the transducer response function coefficients and the stability of the transducers over the course of a season

of observations, the coefficients for one static and one differential

pressure transducer are listed in tables 9 and 10. These values are typical of the calibration results and behavior of the transducers over

the 3 to 4 month period of data collection.

33
Table 9. Transducer response coefficients for the

orifice static pressure measurement

transducer serial number 541529

Date Time Coe fficients - -- Residual Cal.

Constant Linear Quad. Std. Dev. Press.

(psi) (psi/volt) (psi/v2) (psi) (psig)

07/25/85 10 :09 :07 -233.29 128.216 -0.205798 0.150 600.000

07/30/85 09 •15 40 -233.41 128.029 -0.189999 0.237 600.000

07/31/85 08 07 53 -223.54 125.140 0.016461 0.357 640.000

08/01/85 09 05 :39 -239.51 129.766 -0.311400 0.350 610.000

08/02/85 08 20 43 -237.51 129.072 -0.255183 0.169 620.000

08/05/85 07 51 01 -238.78 129.421 -0.285129 0.321 650.000

08/06/85 07 23 :33 -236.17 128.639 -0.229388 0.271 600.000

08/07/85 07 44 56 -238.23 129.157 -0.265026 0.200 580.000

08/08/85 07 23 49 -229.40 126.590 -0.079266 0.208 575.000

08/09/85 07 31 27 -238.70 129.381 -0.285968 0.274 580.000

08/12/85 07 32 15 -232.91 127.651 -0.160128 0.290 585.000

08/13/85 09 45 02 -228.09 126.381 -0.078196 0.436 550.000

08/14/85 07 47 41 -234.65 128.058 -0.188498 0.288 545.000

08/15/85 07 59 50 -234.69 128.101 -0.195160 0.275 550.000

08/19/85 10 27 11 -238.15 129.148 -0.268495 0.309 510.000

08/21/85 07 20 26 -242.77 130.186 -0.330445 0.275 625.000

08/22/85 08 12 28 -242.74 130.261 -0.339371 0.204 620.000

08/23/85 10 50 09 -239.68 129.509 -0.294999 0.305 610.000

08/26/85 09 21 53 -237.16 128.716 -0.236816 0.208 615.000

08/27/85 09 04 39 -235.03 128.227 -0.208538 0.234 605.000

08/28/85 10 29 29 -235.90 128.457 -0.223505 0.237 630.000

08/29/85 10 59 11 -231.74 127.222 -0.137570 0.206 620.000

08/30/85 07 59 25 -242.72 130.231 -0.338824 0.234 595.000

09/03/85 07 41 23 -235.50 128.157 -0.201667 0.210 620.000

09/04/85 07 38 48 -235.84 128.225 -0.205099 0.239 640.000

09/16/85 07 56 08 -240.90 129.606 -0.301820 0.188 500.000

09/17/85 09 18 33 -237.99 128.852 -0.249666 0.555 670.000

09/18/85 09 13 19 -233.63 127.452 -0.143057 0.166 600.000

09/23/85 10 22 51 -230.62 126.663 -0.094247 0.232 710.000

09/24/85 07 00 01 -242.92 129.942 -0.314158 0.216 675.000

09/25/85 08 11 30 -234.01 127.469 -0.139353 0.272 670.000

09/27/85 08 23 51 -238.69 128.893 -0.248900 0.245 560.000

09/30/85 08 26 42 -227.44 125.606 -0.017610 0.242 565.000

34
Table 9. Transducer response coefficients for the

orifice static pressure measurement

transducer serial number 541529 -- Continued

Date Time Coe fficients - -- Residual Cal.

Constant Linear Quad. Std. Dev. Press.

(psi) (psi/volt) (psi/v2) (psi) (psig)

10/01/85 11 11 :30 -237.10 128.551 -0.226510 0.176 580.000

10/07/85 08 24 41 -234.10 127.738 -0.178850 0.307 680.000

10/08/85 07 55 09 -239.12 128.984 -0.257373 0.225 740.000

10/10/85 09 45 00 -240.43 129.421 -0.291259 0.468 670.000

10/18/85 08 42 44 -235.90 127.916 -0.187480 0.201 700.000

10/21/85 08 51 07 -235.84 128.060 -0.204891 0.347 700.000

10/22/85 10 46 05 -233.08 127.128 -0.131176 0.216 650.000

10/24/85 07 49 07 -237.95 128.523 -0.230499 0.363 710.000

10/25/85 09 00 43 -237.77 128.643 -0.246294 0.400 620.000

10/29/85 10 05 57 -237.08 128.361 -0.221312 0.405 670.000

10/30/85 08 29 23 -237.55 128.550 -0.237769 0.414 640.000

10/31/85 08 55 17 -235.09 127.738 -0.176185 0.288 600.000

11/01/85 11 12 27 -237.09 128.317 -0.221875 0.432 670.000

11/05/85 10 17 30 -234.22 127.420 -0.151916 0.158 550.000

11/06/85 09 28 05 -231.30 126.845 -0.126587 0.419 670.000

11/07/85 09 59 58 -232.12 127.018 -0.135807 0.412 630.000

11/11/85 09 08 01 -238.35 128.705 -0.243036 0.218 600.000

11/12/85 09 31 35 -235.60 127.897 -0.189424 0.153 620.000

11/15/85 08 51 53 -237.73 128.449 -0.226050 0.213 520.000

11/18/85 10 01 19 -236.28 128.008 -0.196398 0.225 685.000

11/19/85 09 .48 :00 -236.94 128.164 -0.206596 0.151 670.000

11/21/85 09 :12 :24 -235.08 127.683 -0.166131 0.164 500.000

35
Table 10. Response coefficients for differential

pressure transducers HW-003 and HW-004

Date Time Coefficients Residual Cal.

Constant Linear Standard Press.

(psi) (psi/volt) (psi) (psig)

07/25/85 10 :00 14 -0.3589 0.1807459 0.00036 600.000

07/30/85 09 :09 :07 -0.3579 0.1807354 0.00065 600.000

07/31/85 07 :58 54 -0.3583 0.1807613 0.00027 640.000

08/01/85 08 :45 24 -0.3574 0.1805631 0.00062 610.000

08/02/85 07 :39 •01 -0.3564 0.1806426 0.00082 620.000

08/05/85 07 :41 36 -0.3577 0.1807001 0.00077 650.000

08/06/85 07 15 37 -0.3587 0.1808040 0.00030 600.000

08/07/85 07 34 31 -0.3583 0.1807104 0.00027 580.000

08/08/85 07 17 02 -0.3577 0.1807273 0.00038 575.000

08/09/85 07 22 02 -0.3596 0.1808294 0.00036 580.000

08/12/85 07 24 38 -0.3594 0.1807854 0.00032 585.000

08/13/85 09 37 34 -0.3580 0.1807022 0.00028 550.000

08/14/85 07 40 18 -0.3615 0.1807443 0.00025 545.000

08/15/85 07 53 10 -0.3580 0.1805939 0.00034 550.000

08/19/85 10 20 11 -0.3586 0.1807643 0.00024 510.000

08/21/85 07 13 27 -0.3572 0.1806690 0.00057 625.000

08/22/85 08 05 17 -0.3593 0.1807630 0.00073 620.000

08/23/85 10 42 43 -0.3580 0.1806722 0.00025 610.000

08/26/85 09 12 09 -0.3584 0.1807353 0.00056 615.000

08/27/85 08 56 11 -0.3587 0.1806638 0.00052 605.000

08/28/85 10 20 23 -0.3580 0.1807844 0.00026 630.000

08/29/85 10 50 33 -0.3577 0.1807424 0.00029' 620.000

08/30/85 07 41 01 -0.3582 0.1807614 0.00039 595.000

09/03/85 07 33 03 -0.3611 0.1807606 0.00029 620.000

09/04/85 07 32 16 -0.3583 0.1807507 0.00019 640.000

09/16/85 07 40 58 -0.3593 0.1806250 0.00050 500.000

09/17/85 08 30 05 -0.3619 0.1807880 0.00042 670.000

09/18/85 08 59 57 -0.3627 0.1808188 0.00024 600.000

09/23/85 10 09 30 -0.3620 0.1808180 0.00026 710.000

09/24/85 06 45 59 -0.3609 0.1807562 0.00022 675.000

09/25/85 08 01 52 -0.3610 0.1807502 0.00033 670.000

09/27/85 08 09 02 -0.3602 0.1808493 0.00077 560.000

09/30/85 08 09 28 -0.3612 0.1807951 0.00040 565.000

36
Table 10. Response coefficients for differential

pressure transducers HW-003 and HW-004

-- Continued

Date Time Coefficients Residual Cal.

Constant Linear Standard Press.

(psi) (psi/volt) (psi) (psig)

10/01/85 10 :54 :28 -0.3618 0.1808015 0.00024 580.000

10/07/85 08 :12 :25 -0.3615 0.1807756 0.00047 680.000

10/08/85 07 :44 :03 -0.3617 0.1808452 0.00033 740.000

10/10/85 09 :36 :56 -0.3630 0.1807446 0.00028 670.000

10/18/85 08::26 :16 -0.3617 0.1808375 0.00020 700.000

10/21/85 08::31::54 -0.3614 0.1808016 0.00030 700.000

10/22/85 10::29::35 -0.3623 0.1808268 0.00037 650.000

10/24/85 07::36::10 -0.3619 0.1808477 0.00034 710.000

10/25/85 08:;45::58 -0.3611 0.1808794 0.00035 620.000

10/29/85 09::52::36 -0.3615 0.1807962 0.00021 670.000

10/30/85 08::16::28 -0.3620 0.1808396 0.00021 640.000

10/31/85 08::39::14 -0.3611 0.1807720 0.00030 600.000

11/01/85 10::59::36 -0.3615 0.1807993 0.00030 670.000

11/05/85 09:;50::22 -0.3614 0.1807656 0.00031 550.000

11/06/85 09::08::12 -0.3702 0.1808140 0.00034 670.000

11/07/85 09:;37::35 -0.3614 0.1808146 0.00029 630.000

11/11/85 08::42::34 -0.3615 0.1808274 0.00022 600.000

11/12/85 09::17:;39 -0.3620 0.1808664 0.00022 620.000

11/15/85 08: 28::56 -0.3625 0.1809411 0.00025 520.000

11/18/85 09::48::11 -0.3602 0.1808184 0.00025 685.000

11/19/85 09::33: 02 -0.3619 0.1808329 0.00040 670.000

11/21/85 09::00: 06 -0.3640 0.1811902 0.00148 500.000

37
11. Estimated Uncertainty in the Measurement of Orifice Meter

Differential Pressures

The uncertainty in the estimate of the mean differential pressure value

obtained from the array of 150 observations taken during a test run is

the sum of the following components:

• the uncertainty in differential pressure working standard used

in calibrating the transducers

,

• the variability of the transducers as estimated by three residual

standard deviations of the fitting procedure applied to the

calibration data for each transducer, and

• the variation in the set of 150 observations of the differential

pressure values as given by s^p^, , the standard deviation of the

mean for the set, divided by the mean, expressed in percent.

The quantity s^p , the relative uncertainty in the observed differential

pressure expressed in percent, may be expressed algebraically as

sAP = 0.018 + 3 (sfp, + s|pji/2^ (9)

where s^p^ = residual standard deviation of the fit to the differential

pressures used in calibrating the transducer for the test run of interest, divided by the mean differential

pressure, expressed in percent.

12. Estimated Uncertainty in the Measurement of Orifice Meter and

Critical Venturi Absolute Pressures

Estimates of the uncertainty in the mean absolute pressures measured in

the four nozzle plenums and at the downstream tap of the orifice meter

are composed of the following:

• the uncertainty in the pressures developed by the deadweight

tester working standard used in calibrating the transducers,

• the variability of the transducers as estimated by three residual

standard deviations of the fitting procedure, Sp^ applied to the

calibration data for each transducer, divided by the mean

differential pressure, expressed in percent,

• the uncertainty in the barometric pressure measurement, and

• the variation in the set of 150 observations of the static

pressure values as given by s-^^ , the standard deviation of the

mean for the set, divided by the mean, expressed in percent.

The relative uncertainty in the deadweight tester is taken as 98 parts

per million, neglecting the small variation in the pressure dependence

of the tare force component. The variability characteristic of each

transducer is taken as three residual standard deviations of the fit

38
used to estimate its coefficient values, corresponding to a 99% con- fidence limit. The uncertainty in the barometric pressure is taken as a constant value of 0.034 psia. The relative uncertainty in an absolute

pressure measurement, Sp , for a test run is given in percent by

Sp = 98 X 10' 3.4 (psia) + 3 (sif + s Pm

,1/2 (10)

13. Summary of Transducer Identifications and Measurement Parameters

Differential Pressure Transducers

Three sets of differential pressure transducers were used over the course of the project. Their designations and ranges are given below.

These designations are stored in the database for each test run.

July 3 - November 11, 1984

Test

1

- Runs

403

' Test

500

Runs

- 970

Serial

Number

Pressure Range

(in. of water)

Serial

Number

Pressure Range

(in. of water)

542130

542131

541822

541823

- 40

- 40

- 200

- 200

542131

610038

606029

606032

- 40

- 40

- 150

- 150

July 31, 1985 - November 19, 1985 -- Test Run Numbers 1 - 932

Serial

Number

HW-003

HW-004

HW-OOl

HW-002

Pre ssure Range

(in . of water)

- 40

- 40

- 200

- 200

Static Pressure Transducers

A single set of static pressure transducers were used throughout the

project. The measured parameter was the same throughout.

Orifice Static Pressure

Nozzle 1 Plenum Pressure

Nozzle 2 Plenum Pressure

Nozzle 3 Plenum Pressure

Nozzle 4 Plenum Pressure

Serial Number 541529

Serial Number 541528

Serial Number 541530

Serial Number 541532

Serial Number 541533

39
E. Temperature Measurements and Uncertainties

Measurements of the flowing gas temperature were made using platinum

resistance thermometers (PRT) mounted in high pressure, stainless steel

thermometer wells. Each thermometer was of the four-wire type with one pair of leads used to carry the current and the second pair used for

sensing the voltage developed across the platinum resistance element

itself. Measurement of each thermometer's normal and reverse current

resistance values were made using two channels of the data logger. The

normal and reverse current resistance measurements obey the usual

convention in which the normal resistance measurements are made using

one pair of leads to carry the 1 milliampere current to the platinum

resistance thermometer while the other set is used to sense the voltage

developed across the resistance. The reverse current case merely

reverses these functions. As a result the resistance of the

thermometer's connection leads is eliminated if the resistance of the

thermometer is taken as the mean of the normal and reverse current

resistance values.

As a check on the resistance measurement function of the data logging

equipment a precision, fixed resistor was connected to two of the

channels and measured with each scan of the data logger. This value was also stored in the database as a check standard and a means of correc- tion of the PRT resistance values should that be necessary.

1. Thermometer Location, Calibration, and Time in Service

During the course of the data collection seasons of 1984 and 1985

several sets of thermometers were used for measurement of the flowing

gas temperature at the orifice meter location and in the nozzle plenums.

Each of these sets was calibrated and the resulting coefficients used

for computation of the temperature of the gas flowing through various

portions of the test loop.

1984 Database Collection Configuration

For the 1984 data collection season, six PRT's were used. These were

initially calibrated at NBS against a standards grade PRT. This

thermometer had been calibrated against the national standards before

being used for this particular calibration. Observations of the

resistance of the six thermometers were made over the range of 50 to

120 °F. The temperature/resistance data pairs were fit to a linear model

for use in computing temperature values from observation of the thermometer resistance when installed in the test loop. The locations and

coefficients for the linear fits are given in table 11. Two thermometers were calibrated for use in the 6- and 10-inch orifice meters respectively. These were installed in both meters in the C section of the meter

run approximately 5 diameters downstream of the orifice plate flange.

40
Table 11. Thermometer coefficients and locations for the 1984 database

Location

1 6 -inch orifice meter

2 nozzle manifold position #1

3 nozzle manifold position #2

4 nozzle manifold position #3

5 nozzle manifold position #4

6 10-inch orifice meter

Intercept Slope

(°F) (°F/ohm)

-429.826 4.61819

-430.494 4.62398

-429.362 4.61259

-430.013 4.61871

-430.569 4.62474

-430.323 4.62011

1985 Database Collection Configuration

Two sets of thermometers were used in the 1985 database collection

activities. Neither was calibrated before the data collection procedures ended, but both were calibrated against the NBS national working

standard PRT in 1986 prior to final computation of the results database

from the observation database. Table 12 lists the thermometer coefficients, serial numbers, and locations for the first set of thermometers used. This set was used prior to October 2, 1985. Unfortunately, when the thermometers installed in the small nozzle manifold

were removed, they were not marked as to location. Therefore, they were

calibrated and the average value of the four was used in computing the

nozzle plenum temperature for nozzles placed in that manifold.

The final set of thermometers was installed and used in database

collection after October 2, 1985. This set was of the direct immersion

type, i.e., inserted into the pipeline without a stainless-steel

thermometer well.

Thermometer Calibration

Calibration procedures were performed on all thermometers used for

temperature measurement by the NBS Pressure and Temperature Division using

national working standards. The resistance of each thermometer was observed at three temperatures, nominally 50, 75, and 100 °F. The

resistance value was measured using the four-wire method described above

with a digital multimeter having 6 digits of resolution. The resistance-temperature data pairs for each thermometer were fit to a linear

model of the form

T = A + BR

where T = temperature (°F), and

R = resistance (ohms)

The values for the intercept and slope obtained from the least squares

fits for all thermometers are given, along with their location in tables

11, 12, and 13.

41
Table 12. Thermometer coefficients and locations

for the 1985 database before October 2, 1985

Location

1 Orifice meter

2 Lg. Manifold #1

3 #2

4 #3

5 #4

6 Orifice meter

7 Sm. Manifold A

8 " " B

9 " " c

" " D

Intercept Slope

CF) (°F/ohm)

-432.054 4.64166

-432.083 4.64336

-431.916 4.64189

-432.234 4.64382

-431.968 4.63854

-432.054 4.64166

-431.943 4.63893

-431.943 4.63893

-431.943 4.63893

-431.943 4.63893

Serial

Number

213407

213398

213403

213400

213399

213407

Average

Coefficient Values for Individual Thermometers Installed

in Small Nozzle Manifold Before October 2, 1985

Intercept

(°F)

Slope

(°F/ohm)

-431.989

-431.888

-431.803

-432.094

4.64032

4.63723

4.63732

4.64086

Mean

S. D.

-431.943

0.126

4.63893

0.00193

Serial

Number

209517

209518

209519

209520

Table 13. Thermometer coefficients and locations for the 1985

database after October 2, 1985

Location Intercept Slope Serial

(°F) (°F/ohm) Number

1 Orifice meter -432.054 4.64166 213407

2 Lg. Manifold #1 -432.083 4.64336 213398

3 #2 -431.916 4.64189 213403

4 #3 -432.234 4.64382 213400

5 #4 -431.968 4.63854 213399

6 Orifice meter -432.054 4.64166 213407

7 Sm. Manifold A -431.674 4.63873 211186

8 B -432.019 4.63834 213401

9 c -432.083 4.64273 213406

10 " " D -432.083 4.64194 213402

42
2 . Temperature Measurement Uncertainty

The uncertainty in the measurement of the flowing gas temperature is

composed of the uncertainty in the standard used to calibrate each

thermometer, and the variation in the performance of each is quantified

by the residual standard deviation to the linear model used to describe

its response. The uncertainty in the standards used in calibrating

these thermometers is 0.02 °F and should be considered systematic in

effect. The residual standard deviation to the fit for all of the

thermometers ranged from 0.04 to 0.05 °F. The larger of these two will

be taken as the value characterizing the response of all of the thermometers. This uncertainty component will be taken as random in nature

with three standard deviations, i.e., 0.15 °F, as the magnitude.

The resolution of the data logger limited the precision of the resistance value stored in the database and used to compute the mean value.

Five digits of numerical precision were used, e.g., resistance values

were stored as 103.52 ohms. The uncertainty due to the numerical

precision of 0.01 ohm corresponds to 0.046 °F which is taken as a random

effect.

An observation of the resistance of each of the five active thermometers

is made with each scan of the data logger and stored in the observation

database. The temperature value used in the computation of the gas

properties necessary to compute the orifice discharge coefficient is the

mean of these 150 observations. The variation in the discharge coefficient has contributions from the uncertainty in each thermometer's

temperature value and from the uncertainty in the mean temperature value

due to variability in the population of 150 observations. The population variability is obtained from three standard deviations of the mean

value of each set of observations. The standard deviation of the mean

value is taken as a random variation. Combination of these uncertainties or variabilities is performed by combining the random components in

quadrature and the systematic components additive ly. The relative

uncertainty, S^ , in percent in the temperature values is expressed as follows

:

St = [(15/T)2 + (3st,)2 + (4.6/T)2]i/2 + 2/T, (11)

where s^^ = standard deviation of the mean temperature divided

by the mean temperature, expressed in percent, and

T = absolute temperature on the Rankine scale.

At a temperature of 75 °F (534.69 °R) having 0.25 °F as the value of

Sjjj^, the uncertainty in the measured value is 0.033%.

43
F. Natural Gas Composition Measurements - Gas Chromatography System

1. Chromatograph Description, Calibration Gas Composition, and

Sample Gas -Handling Procedures

Calculation of the physical properties of the natural gas flowing

through the test loop required measurement of its composition. An ENCAL

gas chromatograph, manufactured by Electronic Associates, Inc. [12], and

designed for natural gas pipeline measurement service, was installed for

this purpose. The system consisted of a set of electrically operated

valves, a temperature controlled chromatograph column/oven compartment,

a thermal conductivity detector, and a control unit. The control unit

could be programmed to calibrate the column and detector and to perform

analyses at specified time intervals. When polled from the computer,

the control unit transmitted the results of the most recent analysis to

the computer for storage. Chromatographic analyses of the test loop gas were made at 13-minute intervals. This interval was used as the basic

timing constraint for the test run timing. A data collection time of

approximately 6 minutes was chosen to allow two successive test runs to

be made between chromatograph analyses.

Gas analyses were based on calibration against standard gas mixtures. A

total of four gas cylinders, two each of two compositions, were purchased for use as gas composition reference standards. These mixtures

were specified to have compositions very near the average compositions

of the two gas streams used in acquiring the flow test data. The

composition and uncertainty for each mixture as specified by the

manufacturer, Scott-Matheson [12], are given in table 14. Each of the

gas samples was prepared gravimetrically and contained in 200 standard

cubic foot pressure cylinders. The pressure of each cylinder was approximately 600 psig when delivered.

Calibration of the chromatograph was run automatically each night. The

result of a calibration was a set of response factors which represented

the ratio of the integrated output of a detected peak to the known

concentration of a component in the standard gas. The information

entered into the chromatograph controller for proper calibration were

the composition of each component and its approximate elution time from

the column. Because the system used a backflush method, the C6+

fraction was passed to the detector earliest, followed by nitrogen,

methane, etc. The backflush time was also programmed into the control

unit.

Sample or calibration gas must be maintained at a sufficiently high

temperature to insure that all components are in the gas phase. Should

this not be the case, the chromatograph column performance would vary

over time, causing the component elution times to shift. In an extreme

case, a component could be recognized as the preceding or subsequent

component in the sequence. NGPL personnel at the Joliet test site took

care to monitor the calibration behavior and adjust the timetable

accordingly.

44
Table 14. Gas chromatograph reference gas sample composition

Amarillo Reference Gas

Component Requested Variation Actual Concentratio

Cone. tolerance

mole% ppm mole % mole %

Nz 2.700 100 2.7000 2.7010

CO2 0.600 100 0.5989 0.5990

Methane 91.40 500 balance balance

Ethane 3.750 100 3.7510 3.7576

Propane 1.000 100 1.0000 1.0010

Isobutane 0.150 20 0.1500 0.1500

n-butane 0.100 20 0.0998 0.1000

Isopentane 0.100 20 0.1000 0.1001

n-pentane 0.100 20 0.1001 0.1000

Hexane 0.100 20 0.1001 0.1001

Gulf Coast Reference Gas

Component Requested

Cone

.

Variation

tolerance

Actual Coiicentratio

mole% ppm mole % mole %

N2 0.250 100 0.2501 0.2501

CO2 0.600 100 0.6073 0.5990

Methane 96.50 500 balance balance

Ethane 1.750 100 1.7490 1.7490

Propane 0.400 100 0.4003 0.4003

Isobutane 0.100 20 0.1000 0.1000

n-butane 0.100 20 0.0999 0.0999

Isopentane 0.100 20 0.0998 0.0999

n-pentane 0.100 20 0.1009 0.1001

Hexane 0.100 20 0.1005 0.1001

Like changing column performance, unknown changes in the calibration gas

also may cause erroneous analyses. The most likely change occurs when

the gas cylinder is allowed to cool to a temperature near or below the

dew point of the heavier components, allowing them to wholly or partially condense. To avoid this situation, the calibration gas cylinders

were enclosed in a thermostated cabinet located in the transducer room

of the control shed. These metal, insulated cabinets were maintained

near the set point of the thermostatically controlled heater (95 °F),

thereby minimizing the possibility that separation occurred in the

calibration gas cylinders.

Since the gas chromatograph was located in the control room of the

instrumentation shed, the lines connecting it to the calibration gas

cylinders and to the test loop were rather long. To eliminate the

possibility of condensation of the heavier components, the connection

lines from the thermostated cabinet and from the test loop sampling

point were wrapped with electrically heated tape and insulated along

45
their entire length. The set point temperature at which these lines

were maintained was well above 100 °F.

The line from the test loop sampling point was fitted with a controlled

leak downstream of the chromatograph inlet to insure sufficient flow in

the sampling line and to have minimal delay between gas entry at the

sampling point and arrival at the chromatograph sampling inlet. The

test loop sampling point was located a short distance upstream of the

Sprenkle flow conditioner of the orifice meter run. The pressure in the

calibration gas and sample gas lines was regulated to 20 psig immediately upstream of the chromatograph inlet.

2. Gas Analysis Reproducibility

In terms of the heating value of the gas, the manufacturer's stated

reproducibility for the chromatograph is plus or minus 1 BTU/standard

cubic foot of gas. For the purpose of these tests, a more useful value

is the compositional variation when a single sample is repeatedly

analyzed. During studies of the reproducibility of the measurement

systems used in this project, tests were run on the chromatograph to

determine the effect on gas composition measurement of interchanging

chromatograph calibration gases. Repeated analyses were made of samples

of Gulf Coast gas. In the first case both calibration gas mixtures were used to calibrate the chromatograph. For the second case repeated

analyses were obtained from a sample cylinder filled previously with

Gulf Coast gas from pipeline shortly before the analyses were performed.

Tables 15 and 16 give the results taken on October 16, 1985. The column

headings of each analysis indicates the calibration gas used.

The first three analyses in table 15 were taken using the Gulf Coast

calibration gas mixture to calibrate the chromatograph. Following these

observations, the last four analyses were taken after calibrating the

chromatograph using the Amarillo calibration gas mixture. The average

specific gravity calculated by the chromatograph control unit was 0.58643 for the Gulf Coast gas and 0.58693 for the Amarillo gas. The

respective standard deviations were 5.79 x 10" 5 and 5.0 x 10" 5- The

difference between these two averages, 0.00050, and their standard

deviations is statistically significant. This implies that changing the

reference gas has a small but detectable effect on the calculated

specific gravity. The average calculated specific gravity for the seven

analyses in table 15 taken as a group is 0.5867 with a standard deviation of 2.67 X 10"*' corresponding to a 99% confidence limit of 0.14%.

This uncertainty characterizes the maximum variation in measured gas

composition. This gives a means to asses the random variation in gas

composition obtained from the chromatographic system when used with a single standard mixture for calibration of the chromatograph as was done

in the 1985 data collection period. Although there is a detectable

shift in the chromatograph response, this shift will be treated as an instrumental variation in the error analysis.

The concentration observations given in table 16 were obtained immediately after obtaining the analyses given in the rightmost four

columns of table 15, i.e., the chromatograph calibration coefficients

are constant for these analyses. Therefore, these data are representa46
tive of the variation of repetitive concentration observations for one type of test gas using a specific calibration gas. The average calculated specific gravity for these analyses is 0.58689 with a standard

deviation of 0.000038 corresponding to a 0.019% relative uncertainty at

the 99% confidence level. The impact of this variation on computed

density and critical flow factors for the sonic nozzles is discussed in

more detail in Sections III and IV.

Table 15. Repeated analyses of blocked line containing

containing gulf coast gas ( composition in mol e %)

Ref. Gas^ Gulf Gulf Gulf Amar Amar Amar Amar

/Comp

.

n-Hexane 0.02906 0.02946 0.02926 0.02937 0.02912 0.02906 0.02910

N2 0.36384 0.36619 0.36057 0.34768 0.34613 0.34986 0.35015

Methane 95.6843 95.6770 95.6661 95.6118 95.6142 95.6058 95.6102

C02 0.69508 0.69276 0.69574 0.70943 0.70931 0.70977 0.70966

Ethane 2.31571 2.31875 2.32698 2.37820 2.37820 2.37853 2.37860

Propane 0.55849 0.56063 0.56356 0.56730 0.56510 0.56504 0.56497

i- Butane 0.14005 0.14008 0.14142 0.14032 0.13892 0.13979 0.13955

n- Butane 0.12443 0.12592 0.12680 0.12659 0.12790 0.12932 0.12889

i-Pentane 0.05607 0.05563 0.05475 0.05286 0.05710 0.05772 0.05680

n-Pentane 0.03296 0.03296 0.03478 0.03499 0.03315 0.03511 0.03392

Sp. Gr. 0.5864 0.5864 0.5865 0.5869 0.5869 0.5870 0.5869

^ Gulf - gulf coast calibration gas

Amar - Amarillo It ti

Table 16. Repeated analyses of gulf coast gas sample

(composition in mole %)

Ref. Gas^

/Comp

.

Amar Amar Amar Amar Amar Amar Amar

n-Hexane

Methane

C02

Ethane

Propane

i- Butane

n- Butane

i-Pentane

n-Pentane

Sp. Gr.

0.02278

0.44798

95.5366

0.70705

2.37331

0.56143

0.13807

0.12652

0.05432

0.03198

0.5869

0.02479

0.39926

95.5717

0.70859

2.37654

0.56233

0.13891

0.12733

0.05711

0.03339

0.5869

0.02578

0.37451

95.5983

0.70737

2.37427

0.56370

0.13926

0.12823

0.05544

0.03310

0.5868

0.02685

0.36632

95.6012

0.70784

2.37389

0.56457

0.13956

0.12877

0.05712

0.03388

0.5869

0.02761

0.36331

95.5962

0.70888

2.37983

0.56554

0.13933

0.12864

0.05700

0.03367

0.5869

0.02885

0.35495

95.6032

0.70963

2.37923

0.56487

0.13950

0.12882

0.05714

0.03383

0.5869

0.02902

0.35222

95.6091

0.70962

2.37566

0.56468

0.13978

0.12864

0.05769

0.03362

0.5869

47
G. Orifice Meter Installation and Dimensional Measurements

The tests described here were run using 6- and 10- inch orifice meters

also used in the intermediate Reynolds niimber project of the API orifice

meter data base program [1]. Dimensional measurements of the orifice

plates and meter tubes are described here and in the report of that

project. The configuration of the meter tube/flow conditioners is

similar to that of the other project. A 16-lnch flow conditioner casing

was built especially for use with the 10- inch meter runs in these tests

but not used in the water project. The 10- inch flow conditioner used

with the 6-inch meter tubes is a smaller version of the 16-inch con- ditioner.

The testing sequences in 1984 and 1985 were similar in that one 6- and

one 10- inch meter tube were tested with all of the orifice plates for

each meter size. During the 1984 data collection season the meter tubes

designated FE-7ABC (6-inch) and FE-OABC (10-inch) were used in gathering

the test data. The FE-7ABC meter tube had not been used in the intermediate Reynolds number project at NBS-Gaithersburg prior to these

tests. The surface finish had been measured previously while the meter

tube was involved in testing performed at the NBS -Boulder laboratories

[16]. The surface finish of the meter tube was 77 to 172 microinches

rms . This value is well within the range specified by AGA Report No. 3

[5]. Subsequent to the tests and measurements reported in [16], the

meter tube was involved in tests run at CEESI in early 1984. Prior to

performing these tests the meter tube was brushed with a brass bristle

brush of appropriate size. The interior surfaces of the meter tube

sections had a light dusting of rust ascribed to the action of atmospheric condensation. This meter tube was inspected by Mr. Loy Upp,

API -designated representative, and by Mr. G. G. Less, the NGPL project

manager, and found acceptable for installation and testing with a surface finish within the upper range of surface roughness specified in

AGA Report No . 3 [ 5 ]

.

The 10- inch meter tube FE-OABC had been run previously in the intermediate Reynolds number project. The effects of surface corrosion on

the Interior of the meter tube sections were substantial. The surface

roughness was judged to be outside the limits set in the standard

procedures for orifice meter installation, AGA Report No. 3/API Measurement Standard 2530 [5]. As a result, considerable effort was expended

removing the scaly corrosion from the meter tubes using stiff wire

brushes and sandpaper. This treatment resulted in interior surfaces

having a bright metallic color, being free of rust and well within the

300 microinch root-mean- square surface finish requirement as judged by

Mr. Less.

The orifice meters tested during the 1985 data collection season were similar to those of 1984 with the exception that each of the meter tubes

had been freshly honed. The honing restored the interior surfaces to

surface roughness values well below the 300 microinch limit of AGA3/API

2530. Each meter tube was honed and its diameter measured at NBSGaithersburg before shipment to the Joliet test site. Measurements of

the meter tube diameters were also made at the test site by NGPL

48
personnel. A 6- inch nickel-plated meter tube, PE-8ABC, used In the

intermediate Reynolds number project, was tested in the latter portion

of the 1985 testing program. Surface finish measurements for these

meter tubes are reported in [1] and were in the 100 to 250 microinch

range. Surface finish measurements were made on all the tubes involved

in this project and are reported in reference [1].

1 . Orifice Meter Tube and Flow Conditioner Geometrical Characteristics

and Dimensional Measurements

Conditioning of the flow immediately upstream of the meter tube assembly

was done with the Sprenkle type [17] flow conditioners, which were used

for all three projects in the orifice database program. Location of the

flow conditioner/meter tube assembly was arranged to have the maximum

distance downstream from the heater outlet. The arrangement of the

meter runs in the test loop is shown schematically in Appendix A with

pertinent installation information. The distance between the inlet to

the flow conditioner and the heater outlet was approximately 89 feet.

High pressure casings for the flow conditioners were used for the six

and 10-inch meter runs. The 6-inch casing was used in each of the three

projects. A schematic diagram of the Sprenkle flow conditioner is given

in reference [1]. The flow conditioner consists of three equally spaced

plates. Each plate is perforated with a hexagonal hole pattern. The

plates were welded to four rods S3mraietrically spaced around the circumference of the plates. The diameter of the plate/rod assembly was such

that the assembly fit closely in its respective casing, forcing the flow

through the plate perforations and only minimally along the periphery.

Orifice Meter Tube Geometry and Dimensional Measurements

The general geometry of each set of orifice meter tubes was the same. Three sections formed a set comprising a single meter tube, and 600

pound ANSI flanges were used in all tubes. The Sprenkle flow con- ditioner was bolted to the upstream flange of the approach tube, which

was bolted to the upstream meter tube itself. The orifice plates were

captured between the downstream flange of the upstream meter tube

(length L2 ) and the upstream flange of the downstream meter tube (length

L3 ) . The arrangement of an orifice meter tube and a flange/meter tube

section are shown schematically in figure 5. This diagram is labeled

with several reference positions which were used for measurements of the

meter tube diameters. As shown, two dowel pins were placed in each

orifice meter flange. Additionally, the flanges joining the approach

tube (length L^) and the upstream meter tube were fitted with dowel

pins. This was done to insure reproducible alignment of the approach

tube and the upstream meter tube, and that the centerlines and circumferences of the two tubes were closely aligned. In this way any

misalignment of centerlines between these tube sections was minimized.

Sealing at all flanges except the far upstream and downstream meter tube

flanges was done with 0-ring gaskets machined into each flange face.

These are not shown in the diagram. This eliminated any interference

that a normal insertion type gasket may have caused should it not have

been positioned correctly.

49
1 1

CO -1

1

E

CO

b.coo

\

'

eg

_l

I

/ E

too-k.0)a

\

1

^J

' 1

/

u

COoa

a

<

' 1

D)

0)

a>o

c

a>

k.<D «^O^ k.

Q) k. +^ 0)

0) i* E

o

0}E

k. o

c o

3 E

E

o

c

o o

o

COoa

0)o

0.

O)c a

0) o

00

-J a o

OQ

-1 Q. <

— M

Q.

-co

Q.

Figure 5. Orifice meter tube dimensional measurement locations

50
Also the distance between the orifice tap holes and the orifice plate

faces were much more reproducible than would have been the case with

gaskets. The flange pair at the upstream meter tube/approach tube

combinations were sealed with orifice plates having bore diameter

closely equal to the tube diameter, i.e., /3 = 1.0. These plate bores

were within 0.002 inches of the meter tube diameter to minimize steps in

the diameter profile of the meter tube set.

Dimensional Measurements of the Orifice Meter Tubes at NBS

The schematic diagrams in figure 5 indicate several reference positions

and lengths associated with a meter tube set: the lengths of the three

tube sections and reference positions associated with the diameter

measurements. Diameter measurements were made with a set of internal

micrometers of the type shown in the photograph in figure 6 . This type

of micrometer, designed for the measurement of cylindrical hole diameters, consists of three arms which center the micrometer in the cylinder

to be measured. A small cylindrical rod, approximately 1.5 cm in length

and 2 mm in diameter, forms the contacting surface at the tip of each

micrometer's arm. The readability of each of the micrometers is 0.0001

inches (2.54 micrometers). Each micrometer of the set was adjusted to

read directly using proving rings traceable to NBS length standards.

The proving rings were also used to determine the reproducibility of

diameters obtained using the micrometers once these were properly

adjusted. Typical reproducibilities between operators was 0.0003 inches

(7.62 micrometers) for diameters up to 6 -inches. This decreased

somewhat [0.0002 inches (5 micrometers)] for the smaller diameter meter

tubes. For the 10-inch diameter meter tube the ability to reproduce

diameter measurements was increased to approximately 0.001 inches (25

micrometers) due to the considerably increased difficulty in setting the

micrometer lands in the meter tube in a reproducible manner.

Measurements made at NBS were made in the flow laboratory in which the

temperature is approximately 20 °C. This value varies by 1-2 °C which

introduces a 1-2 part per million systematic contribution to the total

discharge coefficient error budget.

The procedure used to measure the diameter of the meter tube sections at

the orifice flanges involved the four circumferential positions shown in

figure 5, labelled A through D, and the three axial positions labelled

Pj^ through P3 . Although only the diameter near the centerline of the

tap holes (position P^^ ) was used in the calculation of discharge

coefficients (this being the customary position for stating the meter

tube diameter) , three positions along the length of each section were

measured to characterize the contour of the tube near the orifice plate.

Measurement of diameters of both the upstream and downstream meter tubes

were made. Position P2 was located in the region of the weld between

the flange and tubing/pipe forming the tube section. The fabrication of

the meter tubes was such that the regions from the flange face to the

center of the meter tube section had been ground to produce a smooth

surface free from abrupt steps in the diameter. Position P3 was located

approximately one pipe diameter toward the interior of the meter

section, from the weld. In most cases this position was approximately

51
Figure 6. Photograph of internal micrometer with proving ring.

52
two pipe diameters from the flange face. Four measurements of the

diameter were made at each of the three axial positions, except for the

10- inch meter tubes. Diameters were measured for the 10- inch meter

tubes only at positions Pj^ and Pg because the micrometer could not be

read reliably when placed in the third position. At each of these

positions four observations of the diameter were made. One of the three

arms of the micrometer was designated as the reference arm and was aligned with one of the four circumferential positions for each measurement. Out of roundness of the meter tube diameter may be detected in

addition to obtaining four independent measurements of the diameter for

that depth position. Position Pj^ coincided with the centerline of the

tap holes. To avoid the tap holes, measurements at positions A and C

were made with the micrometer's reference arm positioned near the 1 and

7 o'clock positions, respectively. Measurement of the tap hole diameters and location relative to the flange were made. These measurements

are described and the results given in the intermediate Reynolds number

project report [1].

Meter Tube Diameter Measurements Made in 1984 and 1985

A series of measurements of the orifice meter tube diameters was made

over the duration of the API program. Because of the corrosion problem

encountered in the water flow testing of the Intermediate Reynolds

Nvimber project [1] and its subsequent investigation and solution, the

diameter values of the meter tubes changed for the two years of testing

reported in this project. Also the locations of the axial measurement

locations changed somewhat.

The diameter measurement methods used in 1984 are similar to those

described above with the exception of the 10-inch meter tubes. A two

point diameter measurement was used for these tubes . The observation

procedures resulted in diameter observations taken at each quadrant

position at four, rather than three, axial positions for each of the

upstream meter tubes. The axial positions used in 1984 were the

following:

• immediately inside the face of the flange (tops of the lands flush

with the flange face)

,

• 2 to 3 inches inside the flange faces

2 inches for the 2- and 3 -inch meter runs,

2 1/4 inches for the 4- and 6-inch meter runs,

3 inches for the 10- inch meter runs

• in the region of the tube/flange weld, and

• 8 inches from the flange face - 2- and 3 -inch meter runs, 8 1/2

inches from the flange face - 4-, 6-, and 10-inch meter runs.

Although the conventional diameter value for calculation of discharge

coefficients is that observed in the plane of the meter taps, this was not done in the early diameter measurements. The 1984 diameter values

used in analysis of the data collected during that period used the mean

53
diameter observed at position 1, All of the diameter values observed

for meter tubes FE-OABC and FE-7ABC are given in table 17. Measurements

were made before and after running the 1984 tests for the 10- inch meter

tube and are given in table 17.

Since the intermediate Reynolds number project was running concurrently

with this one in 1984 and 1985, meter tubes were moved between the NBS

Gaithersburg, MD site, NGPL in Joliet, IL, and CEESI in Nunn, CO.

Diameter values differ from those used in the 1985 tests due to the need

to recondition the meter tubes, i.e., remove rust from their interior

surfaces

.

The first tube to be tested at Joliet in 1984 was the 6-inch meter tube,

FE-7ABC. This meter tube had been used in a set of NBS/CEESI tests done

in the winter and spring of 1984 and was not tested in water flows until

November 1984. Therefore, any level of rust in the meter tube at the

time of the CEESI tests was due to atmospheric corrosion and judged to

be minimal; however, the meter tube was brushed with a brass bristle

brush immediately prior to installation and use in those tests. The

diameters were measured upon return to NBS in November 1984.

The 10- inch meter tube, FE-OABC, was tested at NGPL beginning on October 12, 1984. Its diameter was measured on March 5, 1984 at NBS

Gaithersburg. It was run in the water flow measurement facility

beginning in May 1984. Significant amounts of rust had formed during

the water-flow tests, and before its installation at Joliet, it was brushed with 10- inch diameter steel brushes and lightly sanded by hand

to restore its surface finish to an acceptable level as judged by the

NGPL project manager. The meter tube was installed in the test run with

no diameter measurements made after it was brushed.

Upon its return to the NBS-Gaithersburg site, diameter observations were

made on January 23, 1985. These are tabulated in table 17. The values

listed are the mean of the observers for each position in the case of

multiple observers. The difference between the values observed in March

of 1984 and January of 1985 differ insignificantly and are within the

uncertainty of the measurement procedures used. Therefore, the value

10.020 inches is used as the diameter for analysis purposes.

Dimensional Measurements of the Orifice Meter Tubes at the Test Site

Measurements of the meter tube diameters were also performed at the test

site by NGPL personnel using a commonly available two-point internal

micrometer. Diameter measurements were made at the same three axial

locations described in the previous section. Because the diameter

measurements were taken with a micrometer which spanned the physical

diameter of the meter tube, a different method of micrometer placement

was used. The micrometer was positioned across four diameters of the

tube. These were labelled H (horizontal), V (vertical), LV (left

vertical) , RV (right vertical) . Tabulations of these measurements are given in table 18. A correction of -0.0006 inches was applied to the 6-

inch meter tube measurements [18].

54
Table 17. Orifice meter diameter measurements made at NBS

in 1984 and early 1985

Meter Tube Section FE-OB

Observation Date - March 5, 1984 Observers SW.GPB.JH

sition A B c D Mean

(inches)

1 10.020 10.020 10.020 10.021 10.020

2 10.023 10.022 10.022 10.021 10.022

3 9.999 10.005 9.998 10.004 10.002

4 10.005 10.019 10.005 10.021 10.012

Meter Tube Section FE-OB

Observation Date - January 23, 1985 Observer GPB

Position A B C D Mean

(inches)

1 10.019 10.020 10.020 10.020 10.020

2 10.026 10.024 10.027 10.025 10.026

3 10.004 10.011 10.007 10.017 10.010

4 10.006 10.007 10.018 10.026 10.014

Meter Tube Section FE-7B

Observation Date - November 11, 1984 Observer GPB

ition A B C D Mean

(inches)

1 6.0603 6.0585 6.0613 6.0622 6.0606

2 6.0582 6.0571 6.0556 6.0552 6.0565

3 6.0598 6.0686 6.0607 6.0569 6.0615

4 6.0629 6.0638 6.0610 6.0557 6.0608

55
Table 18. Orifice meter tube diameter measurements

made by NGPL personnel at the Joliet test site

prior to installation

Orifice Meter Diameter Measurements For Meter Tube Assembly - FE-7ABC

September 4, 1985

Meter Tube Section Lengths

FE-7A 209.75 in. FE-7B 53.9375 in. FE-7C 89.9375 in.

Meter Section - FE-7B

Position

12

3

Diameter Measurements

V LV RV

6.1205 6.1200 6.1209

6.1200 6.1198 6.1201

6.1199 6.1206 6.1201

Diameter Measurements

Position V LV RV

1 6.1193 6.1192 6.1190

2 6.1203 6.1206 6.1187

3 6.1200 6.1213 6.1180

July 18, 1985

Meter Tube Section Lengths

FE-9A 349.75 in. FE-9B 89.875 in. FE-9C 143.875 in.

H Mean Corrected

Mean

6 1204 6.1204 6.1198

6 1200 6.1200 6.1194

6 1201 6.1202 6.1196

M«5ter Section - FE-7C

H Mean Corrected

Mean

6 1190 6.1191 6.1185

6 1193 6.1197 6.1191

6 1196 6.1197 6.1191

O]: Meter Tube Assembly - FE-9ABC

Diameter Measurements Meter Section - FE-9B

Position V LV RV H Mean Corrected

Mean

1 10 .0828 10.0822 10.0832 10 0823 10.0826 10.0826

2 10 .0838 10.0828 10.0824 10 0835 10.0831 10.0831

3 10 0853 10.0848 10.0827 10 0856 10.0846 10.0846

Diameter Measurements Meter Section - FE-9C

Position V LV RV H Mean Corrected

Mean

1 10 0918 10.0918 10.0918 10 .0913 10.0917 10.0917

2 10 0927 10.0916 10.0919 10 .0922 10.0921 10.0921

3 10 0923 10.0913 10.0931 10 0899 10.0918 10.0918

56
Table 18. Orifice meter tube diameter measurements

made by NGPL personnel at the Joliet test site

prior to installation -- continued

Orifice Meter Diameter Measurements For Meter Tube Assembly - FE-9ABC

September 13, 1985

Meter Tube Section Lengths

FE-9A 349.75 in. FE-9B 89.875 in. FE-9C 143.875 in.

Diameter Measurements Meter Section - FE-9B

Position V LV RV H Mean Corrected

Mean

1 10 .0813 10.0812 10.0815 10 0812 10.0813 10.0813

2 10 .0827 10.0809 10.0837 10 .0835 10.0827 10.0827

3 10 .0827 10.0844 10.0857 10 0840 10.0842 10.0842

Diameter Measurements Meter Section - FE-9C

ition V LV RV H Mean Corrected

Mean

1 10 0915 10.0914 10.0913 10 0912 10.0914 10.0914

2 10 .0896 10.0908 10.0899 10 0903 10.0902 10.0902

3 10 .0872 10.0898 10.0862 10 0896 10.0882 10.0882

Orifice Meter Diameter Measurements For Meter Tube Assembly - PE-8ABC

November 4, 1985

Meter Tube Section Lengths

PE-8A 209.75 in. PE-8B 53.9375 in. PE-8C 89.9375 in.

Diameter Measurements

Position V LV RV

12

3

6.0837

6.0925

6.0935

6.0806

6.0915

6.0852

6.0836

6.0937

6.0838

Position

Diameter Measurements

V LV RV

126.0833

6.0800

6.0894

6.0845

6.0810

6.0872

Meter Section - PE-8B

H Mean Corrected

Mean

6.0830 6.0827 6.0821

6.0967 6.0936 6.0930

6.0840 6.0866 6.0860

Meter Section - PE-8C

H Mean Corrected

Mean

6.0823 6.0840 6.0834

6.0924 6.0860 6.0854

57
As mentioned above, corrosion of the interior surfaces of the meter tube

occurred during testing in the intermediate Rejrnolds number project [1].

All meter tubes were involved in test runs conducted in 1984 for that

project. Investigation of the magnitude of surface roughness- induced

effects due to corrosion were conducted between January and June of

1985. The meter tubes were refurbished by honing to remove the effects

of corrosion. Honing enlarged the diameters of the meter tubes to a small degree. Tube diameter measurements were made after honing, which

occurred in 1985. The results of these measurements are given in table

19. The meter tubes were plated with nickel using the electroless

process. The nickel plating provided corrosion resistance to the water

used as the flowing fluid in the intermediate Reynolds number project.

As a test of the effects of the nickel plating on results obtained in

this project, one of the 6 -inch tubes, PE-8ABC, was tested in this

project. The diameter measurements taken on it after plating are also

included in table 19.

Table 20 lists measurements made at both NGPL and NBS (both years). The

agreement between the two are quite good. The NBS values were used for

computation of discharge coefficients and Reynolds number values, using

the uncertainty estimates of the NBS measurements.

2. Orifice Plate Dimensional Measurements and Uncertainties

Orifice plate dimensional measurements were made at NBS only. The

orifice diameter values used in this project are the same as those used

in the intermediate Reynolds number project [1]. The reader is referred

to the report of that project for the pertinent details of the measurement procedures and their results. The orifice diameters used in

computing the discharge coefficient values reported later in this report

are given with the listing of those results.

The room housing the measurement machine was maintained at 20 "C

+0.5 °C during these measurements. The orifice plates were placed in

the room at least overnight before making measurements.

Measurement of the orifice diameter used observation of three coordinate

points approximately equally spaced around the orifice circumference.

The measuring machine then fit these points to a circle to calculate the

value for the diameter. Additionally, the coordinates of the center of

the circle were calculated. This method was combined with three

coordinate measurements along the outer circumference of the plate to

determine the outer diameter and the position of the orifice center

relative to the outside diameter of the plate.

Measurement of the plate flatness was done using several methods. All

of these involved the observation of the height of the top surface of

the plate. The patterns of the observations were all referenced to a line bisecting the orifice and handle of the orifice plate. Three

observation procedures were used which differed in the number and

location of the observations taken to determine the flatness of the

plate. The details of the flatness observation procedures are listed

below.

58
Table 19. Orifice meter tube diameter measurements

after honing and before electroless nickel plating

Orifice Meter Diameter Measurements For Meter Tube Assembly - FE-7ABC

Surface Condition - BARE Observer - GPB Date 08/22/85

Meter Tube Section Lengths

FE-7A 209.750 in. FE-7B 54.000 in. FE-7C 90.000 in.

Diameter Measurements

Position A B

(inches)

1 6.1200 6.1200

2 6.1197 6.1196

3 6.1198 6.1198

Meter Section

C D

FE-7B

6.1200

6.1196

6.1198

6.1200

6.1197

6.1200

Mean

6.1200

6.1197

6.1198

Diameter Measurements

Position A B

Meter Section - FE-7C

6.1183

6.1195

6.1200

6.1185

6.1194

6.1198

6.1182

6.1195

6.1194

D

6.1184

6.1197

6.1198

Mean

(inches)

6.1184

6.1196

6.1197

Orifice Meter Diameter Measurements For Meter Tube Assembly - FE-8ABC

Surface Condition - BARE Observer - GPB Date 07/01/85

FE-8A

Meter Tube Section Lengths

209.75 in. FE-8B 53.875 in. FE-8C

Diameter Measurements

Position A B

6.0833

6.0823

6.0833

6.0928

Meter Section

C D

6.0841

6.1039

6.0861

6.0884

90.00 in.

FE-8B

Mean

(inches)

6.0842

6.0918

Diameter Measurements

Position A B

6.0790

6.0860

6.0846

6.0891

Meter Section

C D

6.0837

6.0812

FE-8C

Mean

(inches)

6.0838 6.0828

6.0914 6.0869

59
Table 19. Orifice meter tube diameter measurements

after honing and before electroless nickel plating

-- continued

Orifice Meter Diameter Measurements For Meter Tube Assembly - FE-9ABC

Surface Condition - BARE Observer - GPB Date 05/13/85

Meter Tube Section Lengths

FE-9A 349.750 in. FE-9B 89.875 in. FE-9C 143.750 in.

Diameter Measurements

Position A B

Meter Section - FE-9B

C D Mean

(inches)

10.0829 10.0829 10.0830 10.0829 10.0829

Orifice Meter Tube Diameter Measurements

After Honing and Before Electroless Nickel Plating

Orifice Meter Diameter Measurements For Meter Tube Assembly - FE-OABC

Surface Condition - BARE Observer - GPB Date 09/24/85

Meter Tube Section Lengths

FE-OA 349.625 in. FE-OB 89.875 in. FE-OC 143.750 in.

Diameter Measurements

Position A B

Meter Section - FE-OB

C D Mean

(inches)

10.0246 10.0254 10.0266 10.0267 10.0258

Orifice Meter Tube Diameter Measurements

After Electroless Nickel Plating

Meter Tube Section Lengths

PE-8A 209.75 in. PE-8B 53.875 in. PE-8C 90.00 in.

Meter Section - PE-8B

sition A B C D Mean

(inches)

1 6.0830 6.0815 6.0824 6.0847 6.0829

2 6.0809 6.0938 6.0774 6.0885 6.0852

3 6.0850 6.0883 6.0893 6.0823 6.0862

Diameter Measurements Meter Section - PE--8C

sition A B C D Mean

(inches)

1 6.0778 6.0835 6.0843 6.0823 6.0820

2 6.0828 6.0895 6.0797 6.0891 6.0853

3 6.0911 6.0885 6.0829 6.0925 6.0888

60
Table 20. Orifice meter tube diameters in the plane

of the tap hole centerlines (axial position 1)

-- NBS Measurements

Meter Tube Diameter

(inches)

FE-7ABC

FE-8ABC

FE-9ABC

FE-OABC

PE-8ABC

NGPL Measurements

Meter Tube Diameter

(inches)

6.0606 (1984)

6.1200 (1985) FE-7ABC

6.0840 FE-8ABC

10.0829 FE-9ABC

10.020 (1984)

10.0258 (1985) FE-OABC

6.0829 PE-8ABC

6.1198

10.0826 - 7/18/85

10.0813 - 9/13/85

6.0821

Four Point Observation

Twelve Pt. Observation

Two pairs of observations were made along the

bisection line on either side of the orifice.

Of each pair one point was located near the

orifice edge and the other near the periphery.

Four sets of three observations were made. Two

sets were made along the bisection line as with

the four point observation with the third point

located midway between the orifice and plate

edge. The remaining two sets were made in a similar way, but along the line perpendicular

to the bisection line passing through the

center of the orifice.

Eight Pt. Observation This series of observations was the same as the

twelve point series but with the middle point

of each of the four sets eliminated.

Measurements of the orifice plates were made throughout the project. In

most cases the initial measurements were made before the plate was involved in flow tests. In a few cases this occurred after flow

testing. These measurements of the orifice diameter were the values

used in computing the results of the tests. In approximately one-half

of the dimensional measurements on the plates, the concentricity of the

orifice and outer diameter of the plate was not determined. Since this

is an important auxiliary parameter, i.e., one that directly influences

the discharge coefficient, a confirmatory set of observations was made

on the orifice plates. This series included

• the orifice diameter,

• the plate outer diameter.

the concentricity of the orifice to the plate

diameter

,

61
• the flatness of the plate using the eight point

observation method, and

• the thickness of the plate.

These measurements are given in the report of the intermediate Reynolds

niomber project [1]. Measurements of edge sharpness were made using the

lead foil technique. These are also described and the results given in

[1].

Table 21 lists the results of the initial dimensional measurements on

the orifice plates tested in this project. For those parameters not

measured, the table entry is zero.

After the testing schedule had been completed in 1985, a set of measure- ments were made on all of the orifice plates used in the orifice test

program. These measurements were designed to incorporate all of the

dimensional measurement procedures for orifice plates discussed above.

Table 22 lists the results of these measurements. In addition to the

orifice plate involved in a series of measurements, a proving ring of

diameter 3.39975 inches at 20 °C was used as a check of the performance

of the multi-axis measuring machine. The proving ring's diameter was measured immediately before and after the sequence of measurements

performed on the orifice plate. These values allow one to judge the

reproducibility and accuracy of the measurements. These measurements

are discussed in more detail in [1].

The quantities listed in table 22 include the following:

ID - orifice diameter,

OD - plate diameter,

Concentricity - the concentricity of the orifice relative to the

plate outer diameter given as the x,y position of

the orifice relative to a set of coordinates with

origin defined by the center of the plate outer

diameter, and

Ring Diameter - diameter of the proving ring, the first column is

the initial result and the second column is the

final result.

Flatness - given in terms of the flatness change over the

orifice dam height, and normalized to the dam

height.

Thickness - measured at four places around the circumference

of the plate.

The flatness value for orifice plate FE-7/8-3A given here differs from

that given in [1] due to a difference in the sequence of data collection

procedures not detected until after publication of [1]. The flatness

value given here is the result of additional analysis of the plate

flatness measurement data and procedures for this plate.

62
Table 21. Orifice plate initial dimensional measurement results

Plate Date Orifice Obs. Plate Ob s . Concentricity Flatn<5SS

I dent. Diam.

(in)

Diam.

(in)

Rad.

(in)

Ang . Obs Ob

(in)

s

.

FE-7/8-1A 05/11/84 1.2494 0.0000 0.0000 0.0000 0.0000

FE-7/8-2A 05/11/84 2.2498 0.0000 0.0000 0.0000 0.0000

FE-7/8-2A -- 2.2501 0.0000 0.0000 0.0000 0.0000

Mean 2.5000

FE-7/8-3A -- 3.0001 0.0000 0.0000 0.0000 0.0000

FE-7/8-3A 05/11/84 3.0005 0.0000 0.0000 0.0000 0.0000

Mean 3.0003

FE-7/8-4A 05/11/84 3.4979 0.0000 0.0000 0.0000 0.0000

FE-7/8-4A -- 3.4990 0.0000 0.0000 0.0000 0.0000

Mean 3.3484

FE-7/8-5A 05/11/84 3.9997 0.0000 0.0000 0.0000 0.0000

FE-7/8-6A 05/11/84 4.4992 0.0000 0.0000 0.0000 0.0000

FE-7/8-7A 02/07/84 0.6252 0.0000 0.0000 0.0000 0.0000

FE-7/8-7A 05/11/84 0.6250 0.0000 0.0000 0.0000 0.0000

Mean 0.6251

FE-7/8-8A -- 1.2503 0.0000 0.0000 0.0000 0.0000

FE-7/8-1B -- 1.2496 0.0000 0.0000 0.0000 0.0000

FE-7/8-2B -- 2.2499 0.0000 0.0000 0.0000 0.0000

FE-7/8-3B -- 3.0004 0.0000 0.0000 0.0000 0.0000

FE-7/8-4B -- 3.4999 0.0000 0.0000 0.0000 0.0000

FE-7/8-5B -- 4.0002 0.0000 0.0000 0.0000 0.0000

FE-7/8-6B -- 4.4997 0.0000 0.0000 0.0000 0.0000

FE-7/8-7B 02/07/84 0.6254 0.0000 0.0000 0.0000 0.0000

^FE-7/8-8B 06/13/86 0.6234 3 9.8731 0.0000 0.0017 0.0055 12

FE-7/8-1C 09/03/85 1.2499 3 0.0000 0.0000 0.0000 0.0037 12

FE-7/8-3C 09/03/85 2.9994 3 0.0000 0.0000 0.0000 0.0018 12

FE-7/8-5C 09/03/85 3.9994 3 0.0000 0.0000 0.0000 -0.0008 12

FE-9/0-1A 05/03/84 1.9987 1 0.0000 0.0000 0.0000 0.0000

FE-9/0-2A 05/03/84 3.7480 1 0.0000 0.0000 0.0000 0.0000

FE-9/0-3A 05/03/84 4.9985 1 0.0000 0.0000 0.0000 0.0000

FE-9/0-4A 05/03/84 5.7488 1 0.0000 0.0000 0.0000 0.0000

FE-9/0-5A 05/03/84 6.6241 1 0.0000 0.0000 0.0000 0.0000

FE-9/0-6A 05/03/84 7.4996 1 0.0000 0.0000 0.0000 0.0000

FE-9/0-7A 05/03/84 1.0001 1 0.0000 0.0000 0.0000 0.0000

FE-9/0-1B 05/03/84 1.9983 1 0.0000 0.0000 0.0000 0.0000

FE-9/0-2B 05/03/84 3.7480 1 0.0000 0.0000 0.0000 0.0000

FE-9/0-3B 05/03/84 4.9976 1 0.0000 0.0000 0.0000 0.0000

FE-9/0-4B 05/03/84 5.7488 1 0.0000 0.0000 0.0000 0.0000

FE-9/0-5B 05/03/84 6.6239 1 0.0000 0.0000 0.0000 0.0000

FE-9/0-6B 05/03/84 7.4997 1 0.0000 0.0000 0.0000 0.0000

FE-9/0-7B 05/03/84 0.9995 1 0.0000 0.0000 0.0000 0.0000

^This plate has a beta ratio similar to the 7B plate. It was a replacement for the FE-7/8-7A plate and marked as shown.

63
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64
III. Calculation of the Mass Flow Rate of Natural Gas Through Critical

Flow Nozzles and Natural Gas Physical Property Values and Their

Uncertainty

Equations are presented in this section which were used to compute the mass flow rate through each of the critical flow nozzles used for a particular test run. These computations depend on experimental data

(plenum static pressure, plenum temperature, and plenum gas composition)

and on computations of the thermophysical properties of natural gas.

The equation developed by Starling, et al .

, as published in American Gas

Association Draft Report No. 8 [2], was used to compute compressibility

factors and sonic velocities. Called SUFERZ, this equation was supplied

to NBS in FORTRAN code form. Extensions to the code allowed explicit

calculations of enthalpy, entropy, density, temperature, and sonic

velocity. The supplied code was converted to the Pascal programming

language and modified to incorporate the required routines into the data

reduction code for the data reported here. A routine called CSTAR was developed to compute the critical flow factor for natural gas. The

algorithm and its application to the data reduction are described below.

A program known as TRAP? [3] was chosen as the method to calculate

viscosities for the natural gas mixtures in this series of tests because

it represented the state of the art in predictive codes for transport

properties. Developed by Ely of the NBS in Boulder, CO, the program is

based on a corresponding states model of fluid mixtures and is applicable to mixtures containing as many as 61 different constituents.

Every effort was made to maintain computational consistency throughout

the sonic nozzle and orifice calculations. With the exception of

viscosity, which was calculated with TRAPP, all fluid properties were

calculated with SUPERZ . Comparisons of calculated and experimental

values for both programs are presented at the end of this section. All

computer programs were implemented on an IBM AT computer with a math co- processor [12]. The internal resolution of the Pascal language implementation used was 11 significant digits. This was found to be

satisfactory for all computations.

A. Derivation of Basic Equations for Gas Flow Rate Through Critical

Flow Nozzles

Mass flow rate through an individual critical flow nozzle operating with

sonic velocity in the throat may be computed from the following equation

[9]:

m = C,AtC*Pp(RTp)-i/2 (12)

where m = mass flow rate,

C^ = discharge coefficient for nozzle,

A^ = area of nozzle throat,

C* = critical flow factor for given conditions,

Pp = upstream or "plenum" pressure,

R = gas constant, and

T = absolute upstream or plenum temperature.

65
The critical flow factor, C* , under assumptions defined below, is a function only of Pp and Tp . C* is defined by [9]:

C* = Gt (RTp)i/V p^^ (13)

where G^ is the ideal mass flux at the throat of the nozzle (mass per

unit time per unit area) , given by

where p^ is the mass density in the nozzle throat and u,. is the sonic

velocity. Calculation of G^ is sufficient to determine the mass flow

rate through the nozzle, but by convention the result is cast in the

form of the C* parameter.

The discharge coefficient C^j relates the performance of a given nozzle

to a perfect critical flow nozzle. In contrast to orifice discharge

coefficient values of approximately 0.6, critical flow nozzle values are generally 0.95 to 1.0. Therefore, when critical flow nozzles are used

to measure mass flow rate, a much smaller "correction" is applied than

that required for orifice plates to convert the "ideal" calculated mass

flow rate to the true mass flow rate.

As described previously, the critical flow nozzles used in this work

were calibrated in air by CEESI [8]. The nozzle discharge coefficients

are given by

C^ = A + B Rd-^/2^ (15)

where A and B are constants and R^ is the Reynolds number, defined as

48m

Rd = (16)

TTd/ip

where m - mass flow rate (lb/sec),

d = throat diameter of the critical flow nozzle (inches), and

/ip = the viscosity of the gas based on plenum temperature and

pressure conditions (Ib/ft-sec).

Usually, the viscosity would be taken at the same point as the diameter

to calculate the Reynolds number. The calibrations of the sonic nozzles

performed by CEESI were based on the Reynolds number as defined by eq

(15) because it contains only measured quantities or properties derived

from measured quantities. Because the throat pressure and temperature

for the critical flow nozzles are not measured during calibration, the

plenum conditions are used to compute viscosity. Discharge coefficient

fitting parameters for each of the critical flow nozzles were siommarized

in table 2.

When the mass flow rate is unknown, eq (12) to (16) are not explicit.

The discharge coefficient depends on mass flow rate and the mass flow

rate depends on the discharge coefficient. This implicit relationship

is the situation for the data treated here. Once the ideal mass flux

66
(G^) is determined for a nozzle, an Iterative procedure must be used to

determine the discharge coefficient, and then the true mass flow rate.

Certain assumptions are required to compute the mass flux or critical

flow factor. The flow through the nozzle is taken to be isentropic and

one dimensional, the plenum velocity is assumed to be zero, and the

throat velocity is assumed to be that of the speed of sound in the gas

for the throat conditions. These assumptions may be expressed as:

AS = Sp - St = (17)

2AH = 2(Hp - Ht) = u2 , (18)

where AS and AH are the entropy and enthalpy changes, respectively, from

plenum to throat conditions, and u^ is the velocity at the nozzle

throat. When an equation of state is available for the flowing fluid,

eq (17) and (18) can be used to determine the mass flux and critical

flow factor. For the reduction of the data described herein, the SUPERZ

equation of state, described above, was used with algorithms developed

at NBS to determine the critical flow factor and other fluid properties.

For the data reduction described here, no corrections were applied to

account for nonzero plenum velocities. Because geometrical data for the

nozzle manifolds were not available, and because these corrections to AH

are very small, it is neither practical nor worthwhile to compute such

corrections

.

B. Derivation of Critical Flow Factor Equations

Equations (17) and (18) depend on the values of the density and temperature in the plenum and in the nozzle throat. With known (i.e.,

measured) values of the plenum properties, eq (17) and (18) constitute

two simultaneous nonlinear equations for the density, p, and temperature, T, in the throat. These equations were solved using Newtonian

iteration. The iterative process was continued until the relative

errors between two successive throat densities and two successive throat

temperatures were each less than 0.0025%. Once p and T in the throat were determined, they were used to compute the ideal mass flux at the

nozzle throat and C* by further computing the sonic velocity at throat

conditions

.

C. Description of Mass Flow Rate Algorithm to Compute Results

for One Rvin

The input conditions to compute mass flow rate through all nozzles used

for one test run were P , T , and the diameters for each nozzle. For a single test run, one to four nozzles were used in one or both manifolds.

The individual flow rates were summed to obtain the total flow rate.

The iterative procedure used to compute C* required many calls to fluid

properties subroutines. The time required to converge to a solution

depended on the number of iterations needed to satisfy the convergence

criteria, which in turn depended on how close the initial estimates for

67
the throat density and temperature were to the true throat density and

temperature. When no other information was available, the ideal gas

values were used as initial estimates [19]:

Pt = 0.65Pp (19)

Tt = 0.83Tp. (20)

With the ideal-gas starting values, about six iterations were required

to obtain the throat density and temperature values to the specified

numerical accuracy.

For those test runs that used several nozzles to achieve the required

mass flow rate through the orifice meter, better initial estimates of

the throat conditions were available. Since C* depends only on the

plenum conditions, test runs with several nozzles had plenum conditions

(and, therefore, throat conditions) which were close for all nozzles in

the test. Thus, once one nozzle in a test run or series of test runs was computed, the calculated throat conditions provided a better

estimate of the throat conditions for the remaining nozzles than the

ideal gas values. This was done when the plenum pressure and temperature were within an arbitrarily defined range of the previously computed

nozzle. When the plenum pressure and temperature were within 1.5 and

0.5%, respectively, of the old values, faster convergence was obtained

using the previously computed throat conditions in place of the ideal

gas values. Computation times for the second and subsequent nozzles

were typically halved relative to the first nozzle.

D. Comparison of Computed and Experimental Values

Several tests were run to determine the level of agreement of the codes

developed for the final computations, done on 16 bit microprocessors,

with the same calculations run on a mainframe computer. The computed

results were also compared with sonic velocity and compressibility data

obtained from samples of Gulf Coast and Amarillo gas.

Numerical Accuracy

A series of tests were run to compare the fluid property values obtained

from the Pascal programs to those obtained from 14-digit mainframe

computer computations. In all cases agreement was within the numerical

accuracy of the 11 significant digits available from the Pascal language

implementation used.

Comparison with Sonic Velocity Data

In addition to the numerical testing, data for sonic velocities in

methane were obtained from the Gas Research Institute [20] . These data

covered ranges of temperature and pressure of 193 to 423 K and 14.5 to

275 bar, respectively. Figure 7 illustrates the good agreement between

the data and computations for temperatures above 400 °R (-59.69 °F) and

pressures below 1000 psia. Except for one point (401.7 °R, 909.8 psi)

which was outside the operating pressure range used at Joliet (480 to

750 psi), the maximum deviation was plus or minus 0.05%. Thus, over the

68
& 0.50

0.25 PL, X

I o

I—

«

o

o

o

0.00

-0.25

-0.50

Deviation of calculated and experimental

sonic velocity values

-a^^

D n „ n ttb %—°—no '-'-nI I I I I I I I I

I

I I I I I I I I I I

I I I I I I I I I I

I I I I I I I I I 200 400 600 800 1000

Pressure (psia)

^ 0.50

0.25

M

Io

o

«o

o

0.00

-0.25 -

-0.50

Deviation of calculated and experimental

sonic velocity values

-fr

D

n

-Wr 1 5

n o-D •e-^

I I I I I I I I I

I I I I I I I I

I

I I I I I I I I

I

I I I I I I I I

I

I I I I I I I I 350 440 530 620 710 800

Temperature (R)

Figure 7. Comparison of experimental and calculated

sonic velocity data.

69
entire range of conditions found in the course of the Joliet tests, the

maximum error in calculated sonic velocity should be less than 0.05% and

the average error less than 0.02%.

For these computational tests, the C6+ fraction was treated as n-hexane

when calculating gas properties. Compared to expanding this fraction to

account for C6, C7, and C8 alkanes, there is less than a 0.01% change in

the computed density. This is indicative of the expected level of

variation in the sonic velocity.

Comparison of Computed and Measured Compressibility Values

During the course of this project the API arranged for measurements to

be made of the compressibility of a sample of Gulf Coast gas. These

measurements were made at the University of Oklahoma using state-of-theart PVT measurements in a modified Burnett apparatus . One of the two

cylinders of chromatograph reference gas was used in these experiments.

The experimental procedures and results were described in an unpublished

report [21] to the API, part of which is reproduced in Appendix D of

this report. These data were used to test the compressibility factors

predicted by the equation of state of Starling, et al . [2].

Values of the compressibility factor were computed at two temperatures

near 60 and 80 °F. These temperatures bounded the range over which the

orifice discharge coefficient measurements were made. The maximum

relative difference between the calculated and measured compressibility

values is 0.041% (see table 23). The differences at the higher temperature are larger than those at the lower temperature and are taken as a conservative estimate of the error in the compressibility values needed

to compute the gas density at the orifice and nozzles.

Table 23. Comparison of experimental and computed compressibility

values for the gulf coast chromatograph calibration gas

Gas Composition (Mole %)

Methane 96.5016 Isopentane 0..0999

Ethane 1.7490 Pentane 0,.0999

Propane 0.4003 Hexane 0,,1001

Isobutane 0.1000 Nitrogen 0,,2501

Butane 0.0999

Compress

Carbon D

ibility Values

ioxide 0,.5990

Temperature Pressure Z Z n Dev.

(Kelvin) (Psia) exp calc

(%)

299.85 763.529 0.90644 0.90617 0.030

299.85 713.566 0.91223 0.91194 0.032

299.85 663.416 0.91818 0.91780 0.041

299.85 613.487 0.92391 0.92370 0.022

299.85 563.554 0.92986 0.92967 0.020

299.85 513.613 0.93581 0.93570 0.012

299.85 463.741 0.94210 0.94177 0.035

299.85 413.745 0.94798 0.94790 0.008

70
Table 23. Comparison of experimental and computed compressibility

values for the Gulf Coast chromatograph calibration gas

-- Continued

Compressibility Values

Temperature

(Kelvin)

Pressure

(Psia)

Z

exp calc Dev.

(%)

288.71 763.416 0.89072 0.89084 -0.013

288.71 713.719 0.89766 0.89762 0.004

288.71 663.742 0.90454 0.90452 0.002

288.71 613.791 0.91148 0.91148 0.000

288.71 563.820 0.91855 0.91849 0.006

288.71 513.860 0.92541 0.92556 -0.016

288.71 463.892 0.93258 0.93267 -0.010

288.71 413.921 0.93978 0.93983 -0.005

288.71 363.987 0.94698 0.94701 -0.003

E. Effect of Compositional Uncertainty on Computed Values

In section II it was shown that the random uncertainty in the chromatographic analysis of composition was plus or minus 0.01% of the computed

specific gravity. In section IV we will develop numerical estimates of

the uncertainty in computed density and critical flow factor using the

known uncertainties in composition.

F. Uncertainty in Natural Gas Density and Critical Flow Factor Due to

Temperature and Pressure Uncertainties

The effects of pressure and temperature uncertainties on the computation

of the critical flow factor and gas density values may be analyzed

numerically. Numerical estimates of the partial derivatives of density

and critical flow factor with respect to pressure, temperature, and

composition are computed in section IV and used to compute estimates of

the density and critical flow factor uncertainties.

G. Determination of Viscosity for Calculation of Reynolds Number

Values of the real gas viscosity were needed to compute Reynolds numbers

of the flowing gas. Throat Reynolds numbers based on plenum conditions

were used to correlate the sonic nozzle discharge coefficients. Values

of the viscosity were required for the range of conditions downstream of

the orifice plates and upstream of the sonic nozzles. These conditions

ranged from 450 to 750 psia and from 510 to 560 °R. The TRA.PP program

described above was used to compute the required viscosity values.

The average temperature and pressure for the orifice and each nozzle

were computed for each test run. These were combined with the gas

composition for the run, and TRAPP was used to compute viscosities for

the orifice and the four nozzles. These values were combined with

appropriate identifying information to form a table for each test run. At the time the results for the test run were computed, this table was used to obtain the viscosities used in the analysis of test run results.

71
IV. Calculation of the Uncertainty in the Orifice Discharge Coefficient

Values Using the Propagation-of-Errors Method

An estimate of the uncertainty in the orifice discharge coefficient

depends on the combined uncertainties in the independent parameter

values on which It depends. Equation (1) indicated these explicit

dependences

Cd = m'^{l-^'yi^

Nd^YF. (pAP)^/2

where C^

m

d

N

Y

Fa

AP

D

= orifice discharge coefficient,

= total mass flow rate through the orifice, = diameter of the orifice,

- a constant whose value depends upon the units

of the measured parameters

,

- density of the flowing fluid, gas in this

project, = adlabatlc expansion factor, = orifice thermal expansion factor, = the differential pressure developed across the

orifice meter, = d/D, the beta ratio, and

= the diameter of the meter tube.

In previous sections we developed algebraic expressions for the relative

uncertainties in each of the various measurands . These components are combined here to derive the relative uncertainty in the discharge

coefficient resulting from the propagation of errors in the observed

parameters

.

As in the development of the uncertainty for each observed parameter,

the random error components are combined in quadrature and the systematic components additive ly. For the total relative uncertainty in

the discharge coefficient expressed in percent, denoted by s , one has

the general expression ^

Yj ac. 5y

s?

J J

1/2

I

dC,

9y,

J s (21)

where y^ = jth parameter in eq (1), — random uncertainty in percent for the

jth parameter relative to that parameter,

= systematic uncertainty in percent for the

jth parameter relative to that parameter.

jr

J s

72
The following describes the individual uncertainties that contribute to

the uncertainty in the discharge coefficient.

A. Analysis of the Total Mass Flow Rate Measurement Uncertainty

The total mass flow rate through the system, and hence the orifice

meter, is the summation of the mass flow rates through the individual

nozzles. The mass flow rate through a single critical nozzle is

determined by the pressure, temperature, and composition of the gas and

the calibration of the nozzle embodied in eq (2) . The uncertainty in

this mass flow rate depends on the uncertainties in these parameters and

on the computed values of the gas properties. The following analysis

first develops an algebraic expression for the uncertainty in the total mass flow rate through the system in terms of the uncertainties in the mass flow rates through the individual nozzles. It then develops an expression for the total uncertainty in the mass flow rate through a single critical nozzle.

1. Uncertainty in the Total Mass Flow Rate Through the Orifice

The total mass flow rate through the orifice, m, is the sum of the mass

flow rates through the individual critical nozzles;

m = S nij^ ,

where m^ is the mass flow rate through the ith nozzle and the sum is over the total number of nozzles operating in a test run. Combination

of the relative uncertainties in the mass flow rates from the individual

nozzles to form the relative uncertainty in percent in the total mass flow rate through the system, denoted by s*, requires, as above, that

the random errors be combined in quadrature and that the systematic

errors be combined additively. In analogy with eq (21), this leads to

the expressions

s • = s • + s • m mr ms

s* = mr

• • S (mi/m)^(s^^)' 1/2

s- = S (mi/m)|(s. )|

mmsc "* 'mo' m. s

where s« (s« ) is the random (systematic) contribution to the

, _. m. r m. s . ,

-"^ ^, , , . . , relative^ error^ m percent m the mass flow rate through the ith nozzle.

73
2. Uncertainty in the Mass Flow Rate Through a Single Critical Nozzle

The mass flow rate through a single nozzle was given in eq (2):

where P

At

Cd

R

T

mm, = PAtC*Cd/(RT)i/2^

nozzle plenum pressure value,

throat area of the nozzle,

critical flow factor for the gas,

nozzle discharge coefficient,

gas constant, and

nozzle plenum temperature.

The random and systematic relative uncertainties in the mass flow rate

through the ith nozzle, in percent, are given by

s» f^ fyj dm, y V/2

1 K dy. 3 r

m^s /_

Yi dm.

% 9y,

'j s I '

where here yj is the jth parameter in the equation for m^ , and sj

j. (s^g)

is the random (systematic) uncertainty in the jth parameter, divided by

that parameter, expressed in percent.

Computational methods and numerical estimates of the relative uncertainties in each observed or computed parameter were given in previous

sections of this report. These are now collected for use in the

expression for the uncertainty in the mass flow rate through a single

nozzle.

Mean Absolute Pressure

Equation (10) gave Sp , the relative uncertainty in percent in the

observed plenum pressure of each nozzle. The random and systematic

contributions were the following:

Spj. - 3 (spf + Spn,)

2 \l/2

'Ps = 98 X 10-^ +

3^4_£sia_ (22)

74
where Sp^ Is the residual standard deviation of the fit used to determine the absolute pressure transducer response coefficients, divided

by the mean pressure, expressed In percent, and Sp^^ Is the standard

deviation of the mean pressure for the observations taken during the

test run, divided by the mean pressure, expressed In percent.

Mean Temperature

Equation (11) gave s^ , the relative uncertainty In percent In the mean

plenum temperature. The random and systematic components were

St, = [(15/T)2 + (3st^)2 + (4.6/T)2]i/2

2/T, 'Ts

(23)

where s^^^ is the relative standard deviation of the mean absolute

temperature value in °R expressed in percent.

Nozzle Discharge Coefficient

The relative uncertainty in percent in the discharge coefficient for a single nozzle depends on the throat diameter of the nozzle. The random

and systematic contributions were given in section II. C as

Cd^

3s

Cdf.

"1 1/2 + 17 X 10"

CdS

0.22 + O.lS'k,

(24)

where k = for nozzle diameters of 0.5328 Inches or less and k = 1 s - is the standard deviation of the fit used to determine

Cjj as a function of Reynolds number, divided by C^ , expressed in percent

otherwise

.

Cjj as a fu: (see table 2)

.

Nozzle Throat Area

Because the temperature of the nozzle during calibration was not the same as its temperature during test runs, there was a systematic

uncertainty in the nozzle throat area, Sj^A, due to thermal contraction

and expansion. The area of the nozzle throat is proportional to the

square of the nozzle diameter, d, given by

d = d„ (1 + aAT),

where d^ is the diameter of the nozzle during calibration, a is the

linear thermal expansion coefficient, and AT is the difference between

75
the nozzle temperature during a test run and that at similar con- ditions , 1 . e . , throat Reynolds number, during calibration with air as the

working fluid.

Uncertainties in nozzle area would not propagate if AT were zero and d^, were used to compute discharge coefficients and experimental mass flow

rates. However, AT was not zero in general, and one must estimate its

effect on nozzle throat area. The term AT can be bounded and its sign

determined by comparing the conditions at the time of nozzle calibration

to the conditions at run time

.

The effective temperature of the nozzle is bounded by the plenum gas

temperature and the throat gas temperature. The actual temperature

depends on the details of the heat transfer between the flowing gas and

the nozzle and between the nozzle and its surroundings. Because the

velocity of the gas varied substantially from the plenum to the nozzle

throat, the heat transfer coefficient varied appreciably along the

entire inner surface of the nozzle. This heat transfer problem was not

sufficiently well-defined for the conditions encountered in this project

to be considered a viable approach for estimation of the effective

nozzle temperature.

Our approach was to establish bounds for the effective nozzle temperature and to combine these with data from the air calibrations to compute

bounds for AT. These values were then used to compute the uncertainty

in the nozzle throat area. This uncertainty was added as a systematic

term to the uncertainty expression for the mass flow rate.

For the NGPL tests in natural gas, the throat temperature varied from

437 to 492 °R, and the plenum temperature from 510 to 570 °R. For the

nozzle calibrations in air, the corresponding ranges were 403 to 440 °R

and 485 to 532 °R. The difference between the throat temperature

(plenum temperature) during test runs and that during calibration is

denoted by AT^ (ATp).

The average temperatures for the calibrations, performed using air as the flowing fluid, were lower than those for the natural gas tests, but

the effective nozzle temperature during test runs could be lower than,

higher than, or equal to the effective nozzle temperature at calibration. A case-by-case approach was used to determine the possible

systematic errors. If AT^ and ATp had the same sign, AT was equated to

the larger of the two; if AT^^ and AT had opposite signs, both positive

and negative uncertainties in the nozzle area were computed.

As an example, let us compare data obtained in test runs in natural gas

for the 0.5328 inch nozzle to air calibration data obtained at CEESI.

[The mean air temperatures are used for each nozzle as there was little

variation in air temperature (mean variation =5.4 °R) for each specific

nozzle calibration. ] The throat temperature at NGPL was 465 °R and at

CEESI 430 °R, and the corresponding plenum temperatures were 542 °R and

520 °R. Thus, in this case AT^, = 35 °R and ATp = 22 °R. Taking the

larger of these as the worst case estimate of AT, one obtains the

76
following estimate of the run- time throat diameter:

a = coefficient of thermal expansion = 8x10"^ in/in °R,

aAT = 8x10"^ X 35 = 2.8x10"'' in/in, and

d = d„ (1 + aAT) = 0.5328(1 + 2.8x10"^ = 0.532949 inches,

where the value of d^ is from table 2. This corresponds to a relative

uncertainty in nozzle area of +0.056%. In this example, there is no additional uncertainty in the throat area in the negative direction.

Similar calculations were made for each nozzle of a test run and an appropriate directional systematic error component was included in the error budget for the mass flow rate.

Critical Flow Factor and Density for Natural Gas

Uncertainties in the critical flow factor contribute to the uncertainty

in the mass flow rate through a single nozzle. Uncertainties in the

density of the natural gas do not, but they do contribute to the error budget for the orifice discharge coefficient. Because the analysis of

these two sources of uncertainty are similar, they are considered

together. The critical flow factor and density depend on three variables: P, T, and x, where x = (xj^ , X2 , ..., Xj^ ) is the vector of mole

fractions for any given case. The total random and systematic relative

uncertainties in these quantities in percent are given by

'C*r

P_

5pr Q* d?

T_

ST

+ 2

J ^j^

xi ac

c 3x,

2'* 1/2

(25)

= hpsi

f

"V p

c*

ac*

ap + hxsl

T ac*

c* aT

+ s |s 1 xi ac*

c* axj

^

(26)

-pr P_ d£_

p^ p ap 'Tr d2_

dT

+ S

J xi l2_

x^ r /3 ax.

2^1/2

(27)

Sps = |spsl p_ d£_

p ap + his I T_ a£.

p dT + S

J h I

' XjS'

Xl d£_

p axj (28)

where s^j^

XjS

the random relative uncertainty in gas component x^

concentration, and

the systematic relative uncertainty.

77
To estimate the uncertainties in critical flow factor and density, the

partial derivatives have to be estimated numerically and combined with

the estimated uncertainties in the pressure, temperature, and mole

fractions

Values of partial derivatives with respect to each mole fraction,

pressure, and temperature were computed using a perturbation method and

the equation of state. The partial derivatives all reached their

(relative) maximums at the same combination of pressure, temperature,

and mean composition: 815 psia, 510 °R, and Gulf Coast gas. These

values of pressure and temperature are reasonable because fluid properties are always most sensitive to system variables at the highest

pressure and lowest temperature. There were small differences between

the Gulf Coast and Amarillo gases with respect to the magnitude of the

partial derivatives at each pressure, temperature combination. Table 24

lists the maximum values of the partial derivatives over the entire 640

point space.

Table 24. Maximum values of the partial derivatives of the

critical flow factor and density of natural gas

with respect to mole fraction, pressure,

and temperature

y Units dC* a^(ib/ft3)

dy ay

Nitrogen mole % -5.03 X

10"'' 1.357 X 10-2

Methane -1.12 X 10-3 -4.49 X 10-2

CO2 5.025 X 10"^ 5.075 X 10-2

Ethane 1.020 X 10-3 3.265 X 10-2

Propane 1.508 X 10-3 6.382 X 10-2

i- Butane 1.500 X 10-3 9.350 X 10-2

n- Butane 1.500 X 10-3 9.500 X 10-2

i-Pentane 2.000 X 10-3 1.245 X 10-1

n-Pentane 2.000 X 10-3 1.275 X 10-1

n-Hexane 2.000 X 10-3 1.570 X 10-1

P psia 8.594 X 10-5 4.063 X 10-3

T d€ig R -4.55 X 10"^ -8.91 X 10-3

To complete the calculation of the uncertainties in the critical flow

factor and the density, the random and systematic uncertainties in the

mole fractions, pressure, and temperature are needed. The uncertainties

in the pressure and temperature were considered previously. The

uncertainties in the mole fractions are considered now. To compute the

random uncertainties in the mole fractions, one must estimate the

variance of the measured mole percent for each component. Since there were no repeated composition measurements during test runs because of

the long turn- around time of the gas chromatograph, the data taken

during tests on the chromatographic measurement system (sec. II. F) are

78
taken as representative of the random uncertainty in composition

measurement. Data for some repeated analyses of both gases that can be

used for this purpose were given in table 15. The associated variances

are given in table 25. A 99% confidence limit is taken to be 3 times

the standard deviation (the square root of the variance). s^ j. , the

random uncertainty in the mole percent for the j th component,-^

expressed in percent, is taken to be 100 times the standard deviation

for that component divided by its concentration in mole percent.

Table 25. Repeated measured compositions of Gulf Coast gas

taken from a sample bottle

Component Variance

Nitrogen 6 942 X 10-5

Methane 1 253 X 10-3

CO2 6 526 X 10-5

Ethane 9 693 X 10-*

Propane 9 137 X 10-6

i- Butane 5 897 X 10-^ n- Butane 2 940 X 10-6

i-Pentane 2 701 X 10-6

n-Pentane 9 517 X 10-7

n-Hexane 2 593 X

10-s

The systematic uncertainties in the composition variables are taken from

the stated tolerances in the gravimetric manufacturing process of the

standard gas samples given in table 26. The values differ between the

two gases because the original specification was in parts per million,

and the molecular weights of the two gases are different. Thus,

conversion to a mole basis generates different values for the two gases.

The molecular weight of the Gulf Coast gas was taken to be 16.865 and

that of the Amarillo gas 17.629. Because the Amarillo gas values have

the larger tolerances, they were used to compute the systematic error

terms in the critical flow factor and density. The systematic relative

uncertainties in percent of the component values , denoted by s , are obtained from the stated tolerances by multiplying by 100 and j dividing by the mole percent.

79
Table 26. Systematic errors In the two chromato graph gas standards

Component Tolerances (mole %)

Gulf Coast Amarillo

Nitrogen

Methane

C02

Ethane

Propane

i- Butane

n- Butane

i-Pentane

n-Pentane

n-Hexane

0.00601

0.05256

0.00383

0.00561

0.00382

0.00058

0.00058

0.00047

0.00047

0.00039

0.00628

0.05494

0.00400

0.00586

0.00399

0.00061

0.00061

0.00049

0.00049

0.00041

Relative Uncertainty in the Mass Flow Rate of Natural Gas Through a Single Critical Nozzle

Combination of the appropriate systematic and random components yields

the following expressions for the random and systematic relative

uncertainties in percent in the mass flow rate through a single nozzle:

s. 3spf 3sPm 1 +

P^ (8.594x10"^)5 n2

f

> 2

' ' +

32 ^Tm +15

2T

I J ^ J

4.6

2T

1 + 4TM4. 55x10"")A \Z

-*2

3s

Cdf

+ 17x10-'' + S

J 3s xi acl

xjr C 3x,

1/2

S.

m. s 98x10-^+ 3.4

1 +

P(8. 594x10'^)

C* 2T

1 +

2T(4. 55x10'^)

C*

+ S Is I 1^ ^

1+ 0.22 + 0.15«k + S„A (syst. area term)

J

' X. S' 'C 5X.

NA \ ^

where k = 1, nozzles throat diameter > 0.5328 inches, and

k = otherwise.

80
The nozzle pressure P in this expression is in units of psia and the

nozzle temperature T is in units of °R.

B. Relative Uncertainty in the Orifice and Meter Tube Diameter Values

The orifice and meter tube diameters contribute relatively small

systematic components to the total uncertainty since the largest two of

the orifice meters are used in this work and the capability to measure

diameters is good. Both of these components are entirely systematic.

The relative uncertainties in percent are

s^ = 0.02/d

Sj) = 0.01/D for 6-inch meter tubes, (29)

Sp = 0.02/D for 10- inch meter tubes,

where d and D are measured in inches.

C. Relative Uncertainty in Natural Gas Density at the Orifice Meter Due

to Temperature and Pressure Uncertainty

The random and systematic error terms for density were developed in

section IV. A. For orifice density, the expression contains the orifice

pressure and temperature rather than the nozzle plenum pressure and

temperature

D. Uncertainty in the Differential Pressure

Equation (9) gave s^p , the relative uncertainty in percent in the

differential pressure measurement at the orifice meter. The random and

systematic uncertainties were given as

SAPr = 3 (s2p^ + s2p^)l/2^ ^^^

(30)

s^P3 = 0.018,

where s^p^ is the residual standard deviation of the fit to the differential pressures used in calibrating the transducer for the test run

of interest, divided by the mean differential pressure, expressed in

percent, and s^p^^ is the standard deviation of the mean differential

pressure for the observations taken during the test run, divided by the

mean differential pressure, expressed in percent.

E. Uncertainty in the Expansion Factor

The uncertainty in this factor is approximately 1 part in 100,000. It

is neglected in calculating the uncertainty in the orifice discharge

coefficient.

81
F. Uncertainty in Orifice Meter Discharge Coefficient

The expression for the total relative uncertainty in percent in the

orifice discharge coefficient is the sum of the random, s^^ij. , and

systematic, s^^g , uncertainty terms described in the previous

paragraphs . One has

where % ^C,r "" %s

Car

> '

r 1

' ^ n m^ 2 r 2

• 2

1=1 nA + X

m

b

^ -^ u

5\2

1 +

P^( 8. 594x10"^)

^*2

3 ^T n, 2 ^n°>

2 r

"^2 11

2T

\. J

f A 9 "\ 4.6

2T.

V y

X

'' 4T2 (4.55x10-'' )2

'

1 +

r*2

3s

Cdf

+ 17x10-'' + S

J 3s

X, ac*

xjr C" axj

3s

Pof

3s P^m

2^ fP^x 4.063x10-3

X

2/^0

3s

T„m

15

To

4.6 fT^x 8.91x10-3 ^2

X

2Pc

+ S

J 1 3s^^!i!^^'

2 "^ /3 3x.

1 ^APf

2

^2

1 ^APm

1/2

82
n

98x10"^ +

3.4

5n^

1 +

Pn( 8. 594x10"=')

IT.

1 +

2T„ (4.55x10-^'

S |s

J XjS

^j dC*

5x, + 0.22 + O.lS'k +

U-)9'J

/S'sd + Sd

98x10 -4 3.4

P„ (4.063x10-3)

2Pc

1 +

T„ (8.91xl0"3)

'

XjS

Xj dp

p axj

0.018

+ SNA

In this expression, subscript 'o' refers to orifice mean values,

subscript 'f refers to standard deviation of a fit, subscript 'm' refers to standard deviation of the mean of a population, and subscript

'n' refers to a mean value at the nozzle plenum. Summations on i refer

to svimming over the four nozzles, and summations on j refer to summing

over the mole fractions of each of the components of the natural gas.

Quantities pertaining to a given nozzle must be evaluated using the

temperature, pressure, etc. pertaining to that nozzle. The units of

pressure are psia, of temperature, °R, and of density, lb/ft''.

G. Example Calculation of Uncertainty Components for One Test Run

In order to illustrate the magnitudes and effects of uncertainties in

the observed parameters, the following discussion addresses one test

run's propagation of error analysis and gives the magnitudes of the

parameters necessary to compute discharge coefficient values

corresponding to each differential pressure value. Test number 150

taken on August 12, 1985 is used. The following tables give the pertinent test run identification information, the gas composition used in

the calculation and the nozzle pressure and temperature observations.

(150 observations of each were recorded.) The standard deviation of the

mean pressures and temperatures and the residual standard deviation of

the fits to pressure transducer calibration data are also listed. It

should be noted that these are not multiplied by three to represent a 99% confidence interval. The remainder of this example calculation is

performed using single standard deviation values. The final results may

then be multiplied by three to obtain 99% confidence limits. For this

test run three nozzles were used to obtain the desired flow rate through

the orifice meter. The second nozzle manifold position is valved off as indicated below. Although the downstream block and bleed valve is

83
test run three nozzles were used to obtain the desired flow rate through

the orifice meter. The second nozzle manifold position is valved off as indicated below. Although the downstream block and bleed valve is

closed for this nozzle, the pressure and temperature transducers were

operative. The analysis program obtained mean and standard deviation

values for these which were ignored in the remainder of the computation.

The gas composition obtained from the chromatograph observation taken at

approximately 7:55 a.m. is the most recent observation and is used for

gas composition input data.

NGPL Orifice Test Point Number - 150

Date - 08/12/85 Time - 08:09:56

Meter tube - FE-9ABC - diameter = 10.0829 inches

Orifice plate - FE-9/0-4A - diameter = 5.7488 inches

Chromatograph Data taken at 0755 hours on 08/12/85

Component Mole fraction Component Mole fraction

Methane 89.860 I-Pentane 0.052

Ethane 4.969 N-Pentane 0.041

Propane 0.917 06 Plus 0.042

I -Butane 0.127 Nitrogen 3.301

N- Butane 0.189 Carbon diox:ide 0.501

Nozzle Plenum Temperature and Pressure Observations

Nozzle

Desig. Plenum

Pressure -- S.D. Mean Fit S.D

(psia) (psia) (psia)

1 1.0648 589.982 0.0077 0.361

2 OFF 589.809 0.0082 0.356

3 .7537 589.695 0.0083 0.425

4 1.3751 589.783 0.0081 0.299

Temperature -- Mean S . D . Mean

(°F) (°F)

70.62 0.0016

69.00 0.0065

70.60 0.0016

70.19 0.0016

Orifice Pressure and Temperature Observations

Mean S.D. Mean Fit S.D.

(psi) (psi) (psi)

Diff. Pressure 3.8163

3.8156

Static Pressure 588.539

0.00069 0.0024

0.00067 0.0014

0.010 0.2651

Temperature =70.69 "F, S. D. of the Mean = 0.0016

84
1 . Computation of Uncertainty in the Nozzle Mass Flow Rate

Computation of the various uncertainties contributing to the uncertainty

in mass flow rate through the operating nozzle set is based on the

observation of plenum temperature and pressure which propagate into the

various parameter values necessary for computation of the nozzle mass

flow rate. The following treats each contribution to the uncertainty in mass flow rate.

Pressure and Temperature Relative Uncertainty

The initial computation is that of the random and systematic components

of the plenum pressures and temperatures. These are obtained from the

forms of eq (22) for the pressure terms and eq (23) for the temperature

terms. The equations are modified for this computation only, and we remove the factor of three associated with the 99% confidence limit.

The values listed are given in relative terms in percent in keeping with

the propagation of errors analysis. The random and systematic com- ponents of the uncertainties in pressure and temperature are listed

below for the three operating nozzles. Nozzle designations correspond

to the nozzle throat diameter in units of inches.

Nozzle Uncertainty Components

Desig. Pressure Temperature

Random Syst. Random Syst.

(%) (%) (%) (%)

1 1.0648 0.0681 0.0152 0.0049 0.0019

3 0.7537 0.0722 0.0152 0.0049 0.0019

4 1.3751 0.0593 0.0152 0.0049 0.0019

Relative Uncertainty in the Critical Flow Factor for Natural Gas

Computation of the uncertainty components associated with the critical

flow factor, C* , using eq (25) and (26) yields the results given below.

Three terms are involved which reflect the uncertainty due to pressure,

temperature, and composition measurement. As discussed previously the

gas composition terra involves summations of random and systematic

effects over all components. These involve the appropriate partial

derivatives, variances, and tolerances, tabulated in tables 24, 25 and

26. The value of the square of the random composition term, the last

term in eq (25), is 2.658 x lO'^/C*^. The value of the corresponding

gas composition term for the systematic uncertainty component in the

critical factor is 8.332 x 10"^/C*. The systematic term's value is

obtained using the Amarillo Gas composition tolerances given in table 26

which gives the worst case estimate. The resulting uncertainty com- ponents for the critical flow factor in percent of the nozzle mass flow

rate are listed below.

85
Nozzle C* Uncertainties

Deslg. Random Syst.

(%) (%)

1 1.0648 0.69936 0.0095 0.0143

3 0.7537 0.69934 0.0097 0.0143

4 1.3751 0.69946 0.0092 0.0143

Uncertainty in the Nozzle Discharge Coefficient

Computation of the random component of the nozzle discharge coefficients

combines the uncertainty in pressure and temperature measurements

involved in nozzle calibration and the fitting uncertainty of the

interpolating equation used in computing the nozzle discharge coefficient as shown in eq (24) . The values for the random and components

are given below in percent of the mass flow rate through the nozzle for one standard deviation in the random component. The systematic com- ponent reflects the use of the secondary system used in all of these

nozzles' calibration.

Nozzle -- Nozzle Cd -- Desig. Random Syst

(%) (%)

1 1.0648 0.0606 0.37

3 0.7537 0.0282 0.37

4 1.3751 0.0431 0.37

Uncertainty in the Nozzle Throat Area

As discussed previously the use conditions of the nozzle in natural gas

flows were not the same as the calibration conditions. Computation of

the relative uncertainty in the nozzle throat area uses the following

average plenum and throat calibration temperatures for computation of

the positive and negative bounds for this systematic effect.

Nozzle Average Calibration Temperatures

Nozzle Plenum Throat

0.09500

0.12500

0.18800

0.24960

0.37500

0.53280

0.75370

1.06480

1.37510

1.94500

2.33000

523.40 432.73

531.73 439.90

521.80 431.41

525.14 434.06

527.34 435.90

519.69 429.59

511.19 422.79

507.67 420.13

505.75 418.73

487.83 403.68

485.70 403.16

86
Computation of this systematic component requires the computation of the

throat conditions for each nozzle. This is done using the equation of

state calculation and the appropriate thermodynamic considerations. The

pertinent temperatures for this test run are the following:

Plenum and Throat Temperatures and Pressures

for Test Run 150

N<3zzle Plenum -- Throat -- Temperature Diff. Syst.

Press. Temp. Press. Temp. Plenum Throat Unc.

(psi) (°R) (psi) (°R) (°R) (°R) (%)

1,.0648 589.98 530.29 320.80 456.08 22.62 35.95 0.058

0,.7537 589.70 530.27 320.64 456.06 19.08 33.27 0.053

1,.3751 589.78 529.86 320.69 455.69 24.11 36.96 0.059

The temperature differences between the calibration and run conditions

are positive with the throat condition differences the largest. The

systematic uncertainty in the mass flow rate due to differences in the

calibration and use conditions and the associated effect on nozzle

throat area are approximately 0.05 percent of the mass flow rate.

Mass Flow Rate Uncertainty for Individual Nozzles

Combinations of the various components contributing to the random and

systematic mass flow rate uncertainties for each nozzle are tabulated

below. Each of the component uncertainties is entered in relative terms

as a percentage of the mass flow rate through the nozzle. The mass flow

rate through each nozzle and its uncertainty in units of pounds per

second are also listed.

Nozzle

(%)

1.0648 0.068

0.7537 0.072

1.3751 0.059

Random Uncertainty Components

(%)

»C*r

(%)

0.0049 0.0093

0.0049 0.0097

0.0049 0.0092

(%)

m. (lb/sec) (lb/sec)

0.0606 9.660 0.0088

0.0282 4.845 0.0038

0.0431 16.085 0.1193

Total 30.590 0.0153

Nozzle

1.0648

0.7537

1.3751

Systematic Uncertainty Components

(%)

0.0152

0.0152

0.0152

(%)

0.0019

0.0019

0.0019

(%)

0.0143

0.0143

0.0143

CdS

(%)

0.37

0.37

0.37

m.

(%) (lb/sec)

0.058 9.660

0.053 4.845

0.059 16.085

Total 30.590

s.

m^^ s (lb/sec)

. 0444

0.0220

0.0741

0.1405

The relative random and systematic uncertainties in the mass flow rate

through the measurement system are 0.005% and 0.459% respectively.

87
2. Computation of the Uncertainty in Orifice Parameters

Uncertainty of Computed Gas Density at the Orifice

Computation of the uncertainty in the orifice discharge coefficient due

to random and systematic uncertainty components in the gas density may

be calculated using eq (27) and (28) . Both equations contain terms

dependent upon the gas composition and are completely analogous with

those discussed above for the nozzle critical flow factor. Evaluation

of these two terms gives the following value for the square of the

random gas composition term, 3.867 x 10"^, and 0.003505 for the systematic term. Substitution of the appropriate parameter values with

some rearrangement of terms in eq (27) and (28) gives the following

expressions for the relative random and systematic uncertainties in the

orifice density. The terms evaluated in table 24 for the partial

derivatives of the density with respect to the temperature and pressure

are used.

pr [(0.265)2 + (0.00069)2] ^ (1.651 x lO'^)

+ [(0.0016)2 + (0.05)2 + (.0153)2] x (7.939 x lO'^)

+ 3.867 X 10- ^/2/[2(1.9999)]

PS (588.543 X 9.8 x lO'^ + 0.034) x 4.063 x lO'^

+ (0.02 X 8.91 x 10-3) ^ .003505 /[2(1. 9999)]

.

The relative random and systematic uncertainty components of the orifice

discharge coefficient expressed in percent are obtained by multiplying

each by 1/2 (see eq (21)) and by 100%. The values are

s^^ = 0.057%, Sps = 0-101%

Uncertainty in the Observed Differential Pressure

The relative random and systematic uncertainty in the discharge coefficient due to uncertainty in the differential pressures may be computed

using eq (30) and the partial derivative of the orifice discharge

coefficient with respect to the differential pressure, which is 1/2.

Substitution of the values of the standard deviation of the mean and the

residual standard deviation of the fit to the calibration data gives the

following values of the relative random and systematic uncertainties in

the orifice discharge coefficient:

88
Mean S.D. Mean Fit S.D. Unc . In C

Random Systematic

(psi) (psi) (psi) (%) (%)

3.8183 0.00069 0.0024 0.0327 0.009

3.8162 0.00067 0.0014 0.0204 0.009

Uncertainty due to Orifice and Meter Tube Diameter Measurement

Using eq (29) yields uncertainties in the orifice discharge coefficient

due to uncertainty in plate and tube diameters of 0.008% due to plate

diameter measurement and 0.0005% for meter tube diameter measurement.

The magnitude of these errors is small relative to those from other

parameters discussed above.

3 . Computation of the Uncertainty in the Orifice Discharge Coefficient

The random uncertainty in the orifice discharge coefficient may be

computed from the values obtained above. Although the final expression

for uncertainty in C^j is quite complicated, it may be reduced to

combination of three terms in quadrature, the random uncertainties in

(1) the mass flow rate through the system, (2) the density of gas at the

orifice conditions, and (3) the differential pressure, as follows for

the two transducer observation sets:

s_ = [(0.050)2 ^ (0.057)2 +

(0.0327)2]i/2 = 0.083%

s^ = [(0.050)2 + (0.057)2 +

(0.0204)2]i/2 = 0.079%

These values represent a single standard deviation estimate of the

random component. To obtain the 99 percent confidence interval in the

estimate, these values should be multiplied by 3.

Similarly, the systematic uncertainty has two components of the same origin as those above, mass flow rate and differential pressure, in

addition to the systematic effects of uncertainty in meter tube and

orifice diameter measurement.

Sc s " ^-Ss + S^3 + Sp3 + Sj) + Sj

s^ = 0.459% + 0.101% + 0.008% + 0.0005% + 0.009% = 0.577%

C^s

The API has selected ANSI/ASME MFC-2M-1983, "Measurement Uncertainty for

Fluid Flow in Closed Conduits", as a reference standard for calculating

uncertainty of orifice flow discharge coefficients. However, in this

report the authors have chosen the propagation of errors method (to

estimate uncertainty in discharge coefficients) which differs from the

API recommended procedure

.

89
V. Data Acquisition and Control Systems

A. General Description

The data acquisition system used In this project consisted of an eight

bit microprocessor interfaced to the various measurement instruments

described in section II. The microprocessor system utilized the S-100

bus interface with 64 kilobytes of random access memory (64K RAM) , a 20-

megabyte hard disk, a single 8 -inch floppy disk drive for data back-up,

and a serial printer. The interfacing to the measurement system was accomplished using an IEEE-488 interface board and an RS-232C

communications port.

The system software was developed using the BASIC and PASCAL programming

languages for the data acquisition and run time results calculations.

The database was constructed using a database manager having command

interpretation capability. A word processor was used to maintain

computerized notebooks of the operation of the measurement system and

comments concerning operational errors or other notations by the

operators during testing. Compiled BASIC was chosen because of the

increased speed afforded both measurement and computational functions.

The compiled PASCAL programs were used to perform computations of the

preliminary results more quickly than could be done with BASIC programs.

The database management software was used to maintain the database files

generated by the system and to generate operator selection menus on the

control console.

B. Data Acquisition System Hardware

The eight bit computer controlling the data acquisition and storage

procedures utilized the S-100 interface bus and a Z-80A central processing unit (CPU) based microprocessor. Two interface boards were necessary for communication with the data acquisition system and hardware

associated with the total system, A four port asynchronous communications controller provided four RS-232C serial communications channels.

These were used for input/output operations to the console, printer,

chromatograph , and modem. The second interface was one conforming to

the IEEE-488 standard and used to communicate with the data

acquisition/control system to the computer system. This interface

functions as defined in the IEEE Standard 488-1975.

The data acquisition/control unit provided a front panel display and

keyboard, a real -time clock and an HP- IB interface. It was configured

with a 5 1/2 digit integrating voltmeter and current source. The

digital voltmeter could resolve 1 microvolt signals and yielded excellent common and normal mode noise rejection. The assembly included a programmable current source which, when used with the digital voltmeter,

could be used for high accuracy four terminal resistance measurements

with 1 milliohm resolution. A twenty channel relay multiplexer was used

to multiplex pressure and temperature signals to the digital voltmeter.

90
C. Data Acquisition System Software

The data acquisition system software controlled the two primary data

acquisition procedures of the project, namely the pressure transducer

calibration and orifice test run data acquisition. The software system

was designed to be user-friendly and to involve as little operator

involvement as practicable to minimize error in the database. The only

data not automatically acquired by the computer were the ambient

temperature for the static pressure transducer calibration and the

barometric pressure. The entire system was menu-driven using the

database management system's programming language capability for program

control and data storage functions. The use of console screen menus was decided early in the planning of the project in order to minimize the

possibility of operator error during data acquisition.

The software provided specific instructions displayed on the terminal to

instruct the operator in the next step required by the current task at

hand. Most inputs of a repetitive nature were put into look-up tables

or files so that the operator need only choose a menu item or input an abbreviated response associated with the desired choice. However, a more important function of the software was the use of internal diagnostic procedures which, although transparent to the operator, continuously

monitored the operational integrity of various components of the data

acquisition system.

IEEE-488 Interface Bus Error Detection

Bus error detection for the IEEE-488 interface was used during all bus

operations. The subroutine to check for errors was provided by the

manufacturer and was used to check for the following errors:

1. Illegal function code

2. No listener

3. Service request

4. Timeout error

5. ATN true

6. IPC true

7. Reset S-100 system

8. Illegal error code.

During the entire phase of orifice meter testing, no such IEEE-488 bus errors occurred.

Pressure Transducer Calibration

During differential pressure transducer calibrations, a digital voltmeter was connected in parallel with the data acquisition input channel

for the DDR- 6000 differential pressure working standard to allow visual

monitoring of the output voltage by the operator. This was used to set

the pressure values prior to acquiring data for each calibration point.

The voltages to be set were included in two files, one for the low range

transducers and the other for the high range transducers. These data

files were DPCAL20.TXT and DPCAL200.TXT, respectively. By using files

in this way, the operator was prompted for the DDR- 6000 voltage to set

91
at each step of the calibration procedure. During the static pressure

transducer calibration, the weight stack compositions placed on the

deadweight testers were stored internally in the program as well as the mass values so that the pressure being applied was computed correctly.

In this way data entry of the weight stack designations and mass values

were preselected and not susceptible to operator error. The operator

was instructed via a console display concerning which weights were to

comprise the deadweight tester weight stack for each pressure value.

From these internally stored values the pressures were computed with no opportunity for mistaken entry of the data into the databases.

The transducer calibration procedures were also designed so that the

operator could either restart the current calibration or abort the

entire set of three procedures at any point during the calibration when

an error had been made. The appropriate entries to the system from the

keyboard terminated the selected procedures, one or all three. This

feature was included to minimize lost time because of possible operator

error.

Before each pressure calibration procedure (low differential, high

differential, or static) was completed, the transducer coefficients for

the desired polynomial were computed as well as the standard deviation

for the least squares fit. If the standard deviation was larger than

the value prescribed in the operating procedures, the current calibration, e.g., low range differential transducers, could be rerun by the

operator after entering the appropriate response. This feature was likewise designed to minimize lost time due to operator errors.

Orifice Plate Testing Checks and Diagnostics

More extensive built-in checks by the software system were used in the

orifice data acquisition portion of the software. For example, all

platinum resistance thermometer coefficients were stored in the program

(NGPLTEST) so that a look-up table could link the temperature probes

with their corresponding nozzle or orifice location. The static

pressure transducer coefficients for the downstream nozzle locations

were similarly stored in the program code. Furthermore, the pressure

transducer calibration coefficients computed in the transducer calibration program, CALA88, were read by the data acquisition program so that

no operator intervention was necessary to obtain the most current set of

coefficient data.

The use of menus for operator input was extensive in the test run data

acquisition program, NGPLTEST. The first menu allowed the selection of

the meter tube to be tested. Depending on the choice of meter tube, the

corresponding plate menu was next displayed for the operator. For both

of these menus, the operator needed only to choose a number rather than

to type a complete meter tube or plate designation. A separate routine

in the software system allowed the operator to review these choices to

reduce the possibility of an erroneous input. This software design

enabled the operator to acquire data with minimal errors due to keyboard

entry mistakes.

92
The next menu allowed for the selection of the nozzles in use. Again

the operator chose a number corresponding to his choice. More than one of the nozzle manifold's four locations could be designated as "off",

but the choice of the same nozzle more than once or of more than four

nozzles generated an error message, after which the operator was asked

to re-enter his selection. Prior to the 1985 data acquisition phase, a second nozzle manifold for the five smaller nozzles was added to the

test loop. This manifold also had four nozzle holders. The software

system allowed the operator to choose the proper nozzles as discussed

above with the added constraint that no more than four nozzles could be

in operation at one time, even though eight holders were available.

This constraint was necessary to maintain compatibility with the

database structure used for the 1984 data (see Appendix E for a summary

of the database structures). The use of four of the nozzles allowed the

operator sufficient latitude to select flow rates for the test runs. More nozzles were not needed for this purpose.

Immediately prior to orifice test run data acquisition, the test loop

pressures and temperatures were displayed on the console display for the

operator's benefit. It was necessary to allow the flow in the meter

tube to stabilize before data acquisition could began. The software

system also checked for various conditions in the test loop. For

example, if a particular nozzle location was designated as "off", but a pressure ratio (upstream to downstream) greater than 1.05 existed, the

computer displayed a warning to the operator that a leak might exist at

that location. In addition, if a pressure ratio (nozzle plenum/nozzle

downstream) less than 1.1 existed at a valid nozzle location, then the

computer displayed a message for the operator that particular nozzle

location appeared to be valved off. If the static pressure in the test

loop fell below 480 psia, then the computer warned of dangerously low

pressure to maintain choked flow in the nozzles. Finally, if the

pressure fell below 460 psia, the program was aborted with the message

that the static pressure was too low to continue. This particular data

testing criterion also was useful in checking if the transducer coefficients had been read correctly or stored incorrectly in the file written

by the earlier transducer calibration program.

During the acquisition of orifice data it was necessary to periodically

obtain the current gas composition data from the chromatograph . The

real-time clock in the data acquisition/control unit provided the means

to coordinate the timing needed to prevent "locking out" the computer

while the chromatograph was printing the gas composition information on paper tape. Because the chromatograph completed a gas analysis every 13

minutes, and because communications to the computer via the RS-232C

interface were locked out during its output phase, it was necessary to

allow chromatograph updates only during a prescribed time interval.

Otherwise, the program would have to be restarted, and significant

amounts of time could be lost as a result. The software system provided

the necessary timing. If the data acquisition was delayed for whatever

reason for more than 40 minutes since the last chromatograph update, the

program automatically requested a new set of chromatograph data by

suspending data acquisition operations until the current cycle of the

chromatograph analysis was available for transfer to the computer.

93
Because the backing up of data on floppy diskettes used a data compression algorithm that required a significant amount of time, the software

system also notified the operator when the current time was after 2:00

p.m. Central Standard Time. The operator could then obtain the final

chromatograph analysis of the day prior to appending the orifice data to

the database files. The files were then compressed prior to being

copied onto floppy diskettes (two copies) . This entire procedure

required one to two hours to complete.

94
VI. Calibration and Test Procedures

The following sections present a detailed description of the procedures

used during calibration of the pressure transducers and acquisition of

orifice meter test data. As discussed in section V of this report, the

data collection procedures were automated to the greatest extent

possible consistent with realistic operation of the measurements

systems. The initial objective of this approach was the reduction or elimination of human error in the recording of data. As the system was planned and constructed it became clear that the procedures necessary to

collect the data could be made very uniform in their execution. To this

end a menu driven software system was developed for the database

collection activities. This approach utilized database management, word

processing, and compiled BASIC and PASCAL software modules.

The detailed operating procedures provided by NBS personnel for use by

NGPL personnel are given in Appendix H for both the calibration and

orifice data acquisition portions of the overall software system. These

detailed instructions are not discussed here but are left to the reader.

The purpose of this section is to provide a description of the software

system's operation.

The program and data files for all software systems used at NGPL

utilized the B: drive of the hard disk, which was partitioned into three

logical drives. A:, B: , and C:. The C: drive contained the database

file structures, and the A: drive contained duplicate database files

which could be sent to a remote facility by using the modem connected to one of the serial communications interfaces and the appropriate

communications software. For data security reasons, the files located

on drive A: were the only ones available via remote communications and

were password protected. NBS Gaithersburg personnel had access to all

files on the hard disk (drives A:, B: , and C:) via an unrestricted

password.

A single main menu controlled all operator-selectable tasks. For the

production of the database a relatively fixed sequence of operations was

executed. The database was arranged generally in data blocks which

contained all of the information developed during a single day. Each

data block was begun with a full calibration of the pressure transducers, followed by orifice meter test run data. One of the constraints

in the selection of the length of time allocated to the data blocks was

the amount of data which could be stored on a one megabyte floppy

diskette using the data compression algorithm format. A single orifice

meter tube was tested during one data block with several data blocks

necessary to complete the data for all orifice plates to be tested for

that meter tube.

The main menu for the various tasks performed daily was written in the

database manager command language . The menu as it appeared for the

operators on the console screen, with the exclusion of phone numbers, is

shown below:

95
NGPL ORIFICE TEST MENU

- EXIT

1 - Monitor test loop pressures and temperatures.

2 - Calibrate pressure transducers, compute

transducer coefficients, and append data

to appropriate databases.

3 - Obtain API orifice plate data, compute mean

pressures, temperatures, Re, and Cd, and

append data to appropriate databases.

»»»»»»» 4 - THIS ITEM MUST BE DONE DAILY ! ! ! «««««««

Acquire end of day ENCAL reading, back up

all data on floppy diskette for shipment

to NBS Gaithersburg, initialize NGPL

database files, and put the terminal in

remote mode for data transmission.

Phone numbers - Bill Cleveland - (xxx) xxx-xxxx

Charlie Sindt - (xxx) xxx-xxxx

Enter desired option _

A. Pressure Transducer Calibration

Calibration of the pressure transducers was the first task performed

each day. In order to begin the calibration, the operator would select

item #2 of the main menu. The calibration task was accomplished using

program CAL488, which controlled the calibration procedure itself and

formed the database containing the observed and auxiliary parameter

values. CAL488 also performed the least squares fitting procedures on

the data for each transducer and produced the coefficient database for

them. The basic features of this particular portion of the software

system are shown in figure 8.

The order of the transducer calibrations was

1) 40-inch differential pressure transducers,

2) 250-inch differential pressure transducers, and

3) all static pressure transducers.

The only difference in the differential pressure transducer calibrations

was the range of pressures to be covered. Otherwise, the software

procedures were identical. This method was possible because of the use

of two data files used as input to the calibration procedure, namely

DPCAL20.TXT for the low pressure range and DPCAL200.TXT for the high

range. (Examples of these menus were given in table 6 in Section II.

D

of this report.) These files contained the differential pressure

working standard target voltage values to be set for the desired

differential pressures. The use of external data files allowed the

differential pressure values used for a calibration pass to be changed

easily without changing the operating program in any way. After manual

96
Pressure Transducer Calibration Software

(Main Menu Item #2)

Program Files

Data Files

Database Files

CAL488

Input Data

DPCAL20 .TXT

DPCAL200.TXT

LDPDA.TXT

HDPDA.TXT

STAPRES.TXT

CALIBR.DAT

NGPLDELP

NGPLSTAT

NGPLCOEF

Figure 8. Block diagram of transducer calibration software system.

97
entry of barometric pressure, the operator was instructed to perform the

calibrations in a step-by-step fashion.

The differential pressure transducer calibration procedure was quite

straightforward. After setting the static pressure of the transducers

to a value near the current test loop static pressure, the operator was instructed by messages displayed on the computer's console to adjust the

working standard voltage to the corresponding target voltage to obtain a particular differential pressure value. The initial observation was the zero differential pressure value. This value was necessary to obtain

the working standard's response at zero differential pressure. Any

character except a "4" was then entered to obtain five voltage measure- ments from the appropriate data acquisition system channels for each of

the two transducers currently being calibrated and for the working

standard. (Entering a "4" at this point allowed the operator to either

restart the current calibration or abort the entire calibration

program.) At the completion of the measurement cycle the mean values

for the current data point were displayed for the operator. The operator

could at this point accept the data point or enter a "0" to repeat the

measurement. The date, time, transducer serial numbers, transducer mean

voltages, and working standard mean voltage were stored in a data file

called LDPDA.TXT for the low range transducers. Nine calibration data

points over the range of to 40 inches of water were used for these

transducers. The same procedures were used for the 13-polnt calibration

of the high range transducers over the range of to 200 inches of

water, and the data were stored in a data file called HDPDA.TXT.

The static pressure transducers were calibrated similarly. After the

operator entered the temperature at the dead weight tester location and

the barometric pressure, he was instructed by messages displayed on the

console to place a series of weight stacks on the deadweight tester to

generate a known static pressure. The computer then acquired five

readings from the four static pressure transducers and averaged them.

The restarting and program aborting procedures were identical to those

for the differential pressure transducers discussed above. The calibration consisted of eight or nine pressure points in the range of 500 to

800 psia. The average transducer indications along with temperature,

barometric pressure, weight stack designation, and other information

were saved in a file called STAPRES.TXT.

The transducer calibration coefficients were computed following each

portion of the calibration procedure. The low range differential

pressure transducers were fit to a polynomial of previously determined

degree using the least squares method. The operator was instructed to

repeat the calibration if the standard deviation computed by the fitting

routine exceeded 0.001 psid. A third order fit of the data was used for

the high range differential pressure transducers. If the standard

deviation for these transducers exceeded 0.01 psid, then the operator

was instructed to repeat the calibration. A second order fit was used

for the four static pressure transducers. The standard deviation

maximum for these transducers was 0.6 psia. These calibration coefficients were stored in the data file CALIBR.DAT.

98
Upon completion of all pressure transducer calibration procedures, the

data files LDPDA.TXT and HDPDA.TXT were appended to database file

NGPLDELP . DBF , the data file STAPRES.TXT was appended to NGPLSTAT.DBF,

and the data file CALIBR.DAT was appended to database file NGPLCOEF.DBF

as shown in figure 8. The software system then returned to the main

menu.

B. Orifice Meter Data Acquisition Procedures

Figure 9 shows a block diagram illustrating the logical basis for the

software system used to acquire the flow measurement system data during

orifice discharge coefficient measurement operations. Data acquisition

during orifice meter testing was accomplished using three programs,

NGPL, RENCAL, and NGPLTEST. Using the BASIC "CHAIN" statement, these

three programs were chained together due to memory size limitations of

the computer system. The "%INCLUDE" compiler directive was used along

with the file COMDEF.BAS in order to declare common variables,

functions, and subroutines used by each of the programs. Data acquisition was started by choosing item #3 in the main menu. This choice

loaded and ran the first of the three chained programs. It should be

stressed that the loading of these programs from the systems disk was transparent to the operator, whose menu selections controlled operations

at any time.

NGPL is an initialization program. Its tasks were to initialize

variables and place two zeroes in the data file NUMBFILE.DAT. The data

acquisition software next chained to the program RENCAL (repeated gas

analysis). This program acquired gas composition information from the

chromatograph . It was necessary for the operator to be certain that the

chromatograph was not about to print its previous analysis prior to

beginning orifice data acquisition so that the computer would not become

"locked out", as described in section V. This event was possible only

at the time when item #3 of the main menu was chosen, since the software

system controlled the timing after the start of data acquisition

operations. The date, time, analysis time, and gas composition were stored in data files GCDATA*.DAT. The * indicates ascending numbers

from one up to the number of times the measurement was performed during

testing. After the ENCAL analysis was displayed on the screen, the

system paused until the operator pressed the space bar to continue data

acquisition by chaining to NGPLTEST.

NGPLTEST was the final of the three chained programs and acquired the

orifice discharge coefficient data over the desired flow rate range.

This program first read the contents of the data file NUMBFILE.DAT,

which contained the number of chromatograph analysis files and the

number of orifice test point files that were currently saved on the hard

disk. The program then recalled the previous meter tube, orifice plate, run number, barometric pressure, and nozzle designations from the file

NGPLSTAT.DOC. After the program displayed the transducer calibration

date, the operator entered the barometric pressure and then was presented two menus, one for the meter tube designation and the other

for the orifice plate designation. A carriage return for either menu

retained the designations read from the file NGPLSTAT.DOC. Otherwise,

the designations were chosen with a number that corresponded to the

99
Orifice Data Acquisiton Software System

(Main Menu Item #3)

Program Files

NGPL

Data Files

NUMBFILE

RENCAL GCDATA*

NGPLTEST

Input Data

CALIBR.DAT

NGPLSTAT.DOC

OHEAD*

OPRES*

NGPLNCAL

NGPLHEAD

NGPLPRES

Data Base Files

Figure 9. Data acquisition software block diagram

100
meter tube or orifice plate desired. After the operator made a selection, the software system allowed him to review his entries before they

were finally stored in computer memory.

The next portion of NGPLTEST presented the operator with two nozzle

menus, the first for the large manifold and the second for the small

manifold (for 1985 operations) . Again the operator was to choose a number corresponding to the nozzle installed at each location and his

entries could be reviewed prior to final storage in memory. The number

"12" was chosen for a location that was unused, or "off". As discussed

in section V, the software system checked the choices made by the

operator for duplication of nozzles and for too many nozzles. It should

be stressed at this point that NGPL operating personnel were responsible

for the correct input of the nozzle designations and that if a mistake

was made at this point, there was no means to identify, or to later

recover from, the error. The resulting computed mass flow rate would be

in error, and the computed discharge coefficient likewise would be in error.

The operator was next instructed to enter any comments he might have

concerning weather conditions or anything felt to be out of the ordinary

or worthy of saving in the notebook file. In this way the run time

information by the operators could be kept to help identify errors in

the data collection procedures, e.g., valves were not closed when they

should have been, etc.

The program then entered a scan mode so that the operator could monitor

temperature and pressure conditions in the test loop for stability. This

section of the program displayed the 10 most current values of the

orifice static and differential pressures and of the orifice and nozzle

temperatures . This monitor program could be run at any time from the

main menu by choosing item #1 from the menu. The particular program

used for menu item #1 was called SCAN. Not only did this program

display the temperatures and pressures as described above, but also the

operator could choose to display the orifice static pressure, the

differential pressure values of each of the four transducers, and the

differential working standard's voltage.

As discussed in section V, the monitor section of NGPLTEST also checked

for a pressure drop across a nozzle location designated as off and

monitored the static pressure in the loop so that operation could not

continue if the pressure fell below 460 psia. The operator used this

monitoring function to determine when stable and acceptable conditions

in the flow system were reached. Data acquisition were then initiated

by pressing the space bar on the console. Data acquisition required

approximately 6 minutes for a single test point and, generally, four

test points were taken at a single flow rate. Each orifice plate was tested at 4 or 5 differential pressures up to the maximum allowed by the

currently installed, high range differential pressure transducers at the

existing line pressure in the test loop. (These differential pressures

were selected to yield approximately equal incremental changes in the

Reynolds number over the flow rate range.) During the time of orifice

data acquisition, the data acquisition system read the values from each

of the pressure transducer and PRT elements sequentially 150 times.

101
Each of the 150 voltage values read from the data acquisition/control

unit were stored. Data files OHEAD*.DAT and OPRES*.DAT were used to

store the raw data. Again the * indicates ascending numbers from one up

to the number of times the measurement was performed. The final number

was saved in the file NUMBFILE.DAT to aid in appending of orifice data

to the database files NGPLHEAD.DBF and NGPLPRES . DBF

.

After a single test point was measured, the software system chained back

to RENCAL in order to obtain new gas composition data if the clock

indicated that a new analysis was available. If not, the system

continued with the next test point. The software system continued in a cyclic manner between RENCAL and NGPLTEST" until a single flow rate

observation sequence was completed. Then the system ran a program

called NGPLCNVT, which converted data files to a form suitable for input

to the program NGPLAVGP that computed mean pressures, temperatures, mass flow rate, and discharge coefficient. This program was written in the

PASCAL language to attain the smallest computational time. Finally, the

data were appended to the appropriate database files as described above,

and another ENCAL analysis was obtained using program ENCAL.

After the database files had been appended, the software system called

the word processor to append the file C0MMENT.DOC to a list of notes

kept during the course of the project called N0TEB00K.DOC. This file

contained not only comments from the operator as described above , but

also such data as the date, time, and plate and meter tube designations.

This notebook was an extremely useful tool for the operators as well as the managers of this program in recording the events occurring during

the tests.

After six flow rate observation sequences, or 24 test points, or at the

end of the day, it was necessary for the operator to obtain one final

gas analysis and back up all files on two floppy diskettes using item #4

of the main menu. This portion of the software system ran a program

called FENCAL (final gas analysis) and then used a data compression

algorithm to reduce the size of the data files in order to allow more

data to be stored on a floppy diskette. After the two floppies were

created, one was mailed to NBS-Gaithersburg for analysis, and the other

was kept as a back-up at NGPL. Finally, the software system initialized

all of the necessary files and stopped so that the operator could turn

off the system until the next day.

102
VII. Operating Procedures, Test Rtin Inventory, Test Rim Data Analysis

Results, and Analysis of the Results

The extent of the complete database generated during the course of this

work is quite large. It is stored in computer readable form only and

available from either NBS or API. The bulk of the database consists of

the 150 sets of differential pressure, static pressure, and temperature

transducer observations recorded for each test run. The results of the

analyses of the final database are much less extensive. However,

listing of all the intermediate parameter values for each test run is

not possible here. To keep the size of this report within manageable

proportions, the results for each valid test run are summarized in a single line of information. Plots of discharge coefficient vs. pipe

Reynolds number are also given for each orifice meter. A brief discussion is given of the operational events and the data collection procedures used in collection of the final database since these effect the

test run analysis.

Analysis of the database was done with software having numerical

precision of 12 digits. This was compared with codes of known numerical

accuracy of 8 digits and found to agree at the 8 digit level.

The final database contains the normal operational malfunctions and

blunders encountered in obtaining any experimental database. A detailed

inventory of the test runs which identifies those runs for which

malfunctions occurred and were identified as such is included.

A. Operating Schedule, Final Database Definition, and Archiving

of the Database

A detailed operational history of this project from its inception

through its completion is given in Appendix B of this report. It is

chronological and is largely drawn from the progress reports submitted

to the API over the course of the data collection period. A brief

description of the major events shaping the structure and segmentation

of the database is given here to provide the rationale for elimination

of certain blocks of test runs from the analysis procedures discussed

here.

General Operating Schedules and Database Segments

As mentioned previously the governing consideration of the time periods

for the tests was the outside temperature at the test site. In an attempt to insure that the natural gas temperature in the critical

nozzle throats was above the hydrocarbon dew point, the testing schedule

was conducted during the summer and fall of the year. Identification of

test runs was chronological beginning with test run number 1 for both

years in which data collection was done. Test run numbers were sequential for each year with the exception of beginning test runs in 1985

which were numbered 971 through 974 taken on July 25, 1985.

The four largest meter tubes were tested over the two year period of the

project. The FE-7ABC meter tube was tested in both years. The original

plan for the project was to complete the tests in one year, and to test

103
a single meter tube of each size, i.e., 6- and 10-inch. However, after

completion of the 1984 testing schedule, the effects of variation in the

surface roughness were demonstrated in the intermediate Reynolds nximber

project [1] in the winter and spring of 1985. The API's Orifice Meter

Database Steering Committee decided to repeat the tests in natural gas

in the summer of 1985 with the newly refurbished meter tubes which had

not been subjected to water flows and their attendant corrosive effects.

In addition it was decided to test one of the 6- inch meters after it had

been electroless nickel plated to determine whether any effects of the

nickel plating could be detected in natural gas flows. (All of the

meter runs were electroless nickel plated for corrosion resistance

purposes in the intermediate Reynolds niomber project [1].)

The database in 1984 is divided by events into two segments. The first

segment contains test runs number 1 through 403. These test runs were

taken with the original differential pressure transducers. As described

in Appendix B the high range set of these transducers was found to

exhibit unacceptably large drifts of the zero differential pressure

response and was replaced. The remainder of the test runs collected in

1984 were number 501 and higher and used the replacement high range

differential pressure transducers. Test runs in the first segment taken

at differential pressures below 40 inches of water are considered to be

valid and are included in the final database. All of the test runs of

the second segment of the 1984 test run data are included except for

those indicated by the operators as being in error for a variety of

operational difficulties. These difficulties are noted in the inventory.

The 1985 database is a single segment. All test run data except those

indicated by the operators as having operational difficulties are included in the final database.

The typical daily operating schedule consisted of

(1) calibration of all absolute and differential pressure

transducers

,

(2) computation of calibration coefficients for each transducer,

(3) test run data collection and analysis procedures, and

(4) data compression and storage.

Flow set points were generally selected to span the Reynolds number

range possible for each orifice meter in approximately equal increments.

However, this was not always realized due to changing pipeline pressure

and the finite number of nozzles as flow standards.

Test series (a set of consecutive test runs for a particular Reynolds

number range) were replicated at least once except in the latter

portions of the testing seasons when replications were not possible due

to the weather. Generally, this was done on a different day. In many

cases the orifice plate was removed from the meter tube between replications .

104
B. Inventory of the Final Database

The final database consists of the two 1984 segments and the 1985

segment. The inventory of the final database is given in table 27, and

is arranged by meter tube and orifice plate. Each section of the

inventory table has a listing of the test run blocks analyzed and those

marked for deletion. The causes for deletion are given in the comments

column. Several causes were recurrent throughout the testing. These

have been assigned a character code which is given in the comments

column. These codes are listed below. Otherwise, specific causes are cited for the deletion. Those test runs marked for deletion were so marked as a result of operator observations of malfunction in the

measurement, orifice meter or pipeline systems. No other basis was used

for identification of a test run as deleted with one exception. Test

runs taken in the early portion of 1984, through August 20 (1-403), were

taken with high range differential pressure transducers which showed

considerable zero drift. Test runs taken during this period having a differential pressure value greater than 40 inches of water are eliminated from the list of acceptable runs. These test runs are listed

in the deleted run section of the inventory, but are contained in the

archival data files. These test runs were only deleted from the

analysis and were not physically deleted from the database. All runs recorded are archived. Some runs were interrupted before the observed

data were recorded by the data acquisition system. These were never

available and are not contained in the archival record of the database.

Deletion Comment Codes

# - Keyboard entry error. Improper responses were given by

the operator to the data acquisition microprocessor.

+ - Run numbering skip.

* - Operator Indicated Deletion, no specific notation as to cause.

! - Test runs taken in early 1984 having differential pressures

above 40 in. of water.

The inventory constitutes a list of acceptable and unacceptable test

runs. As mentioned above the criteria used for labelling test runs as unacceptable are based solely on the identification of operational

difficulties at the time of the test or because segments of test runs were recorded for diagnostic purposes.

105
Table 27. Inventory of observation runs.

Date Meter Orifice Run No. Num.

Tube Plate Beg. End Rui

09/10/84 FE-7ABC FE-7/8-1B 501 504 4

09/11/84 FE-7ABC FE-7/8-1B 505 512 8

09/12/84 FE-7ABC FE-7/8-1B 513 520 8

09/23/85 FE-7ABC FE-7/8-1B 397 412 16

10/07/85 FE-7ABC FE-7/8-1B 513 528 16

10/31/85 FE-7ABC FE-7/8-1B 700 719 20

08/15/84 FE-7ABC FE-7/8-2A 344 355 12

09/20/84 FE-7ABC FE-7/8-2A 586 597 12

09/21/84 FE-7ABC FE-7/8-2A 598 609 12

08/16/84 FE-7ABC FE-7/8-2B 374 379 6

08/20/84 FE-7ABC FE-7/8-2B 380 391 12

09/24/85 FE-7ABC FE-7/8-2B 413 420 8

09/27/85 FE-7ABC FE-7/8-2B 460 483 20

10/30/85 FE-7ABC FE-7/8-2B 678 699 20

08/07/84 FE-7ABC FE-7/8-3A 236 259 24

08/10/84 FE-7ABC FE-7/8-3A 308 319 12

09/30/85 FE-7ABC FE-7/8-3A 484 504 19

10/01/85 FE-7ABC FE-7/8-3A 505 508 4

10/29/85 FE-7ABC FE-7/8-3A 658 677 20

08/13/84 FE-7ABC FE-7/8-3B 332 337 6

09/24/84 FE-7ABC FE-7/8-3B 610 629 20

08/03/84 FE-7ABC FE-7/8-4A 176 187 12

08/13/84 FE-7ABC FE-7/8-4A 338 343 6

09/26/84 FE-7ABC FE-7/8-4A 630 651 20

08/06/84 FE-7ABC FE-7/8-4B 206 217 12

10/01/85 FE-7ABC FE-7/8-4B 509 512 4

10/25/85 FE-7ABC FE-7/8-4B 638 657 20

Runs

72

36

66

79

26

38

36

106
Table 27. Inventory of observation runs --- Continued

Date Meter Orifice Run No. Num. of Total

Tube Plate Beg. End Runs Runs

07/09/84 FE-7ABC FE-7/8-5A 37 45 8

07/13/84 FE-7ABC FE-7/8-5A 46 51 6

07/18/84 FE-7ABC FE-7/8-5A 65 70 6

07/23/84 FE-7ABC FE-7/8-5A 85 96 12

07/25/84 FE-7ABC FE-7/8-5A 98 109 12

09/28/84 FE-7ABC FE-7/8-5A 672 691 20 64

07/26/84 FE-7ABC FE-7/8-5B 110 121 12

10/24/85 FE-7ABC FE-7/8-5B 618 637 20 32

07/03/84 FE-7ABC FE-7/8-6A 1 6 6

07/05/84 FE-7ABC FE-7/8-6A 7 12 6

10/01/84 FE-7ABC FE-7/8-6A 692 703 12

10/03/84 FE-7ABC FE-7/8-6A 704 711 8

10/22/85 FE-7ABC FE-7/8-6A 606 617 12 44

07/31/84 FE-7ABC FE-7/8-6B 140 151 12

10/08/85 FE-7ABC FE-7/8-6B 529 536 8

10/10/85 FE-7ABC FE-7/8-6B 537 540 4

10/21/85 FE-7ABC FE-7/8-6B 598 605 8 32

09/14/84 FE-7ABC FE-7/8-7A 541 560 20 20

09/17/84 FE-7ABC FE-7/8-7B 561 572 12

09/18/84 FE-7ABC FE-7/8-7B 573 578 6

09/16/85 FE-7ABC FE-7/8-7B 373 380 8

09/17/85 FE-7ABC FE-7/8-7B 381 388 8 34

09/12/84 FE-7ABC FE-7/8-8A 521 528 8

09/13/84 FE-7ABC FE-7/8-8A 529 540 12 20

11/01/85 FE-7ABC FE-7/8-8B 720 739 20 20

Total Test Runs 619

107
Table 27. Inventory of observation runs -- Continued

Deleted Runs

Date Meter Orifice Run No. Num. of

Tube Plate Beg. End . Runs

Comments

09/18/85 FE-7ABC FE-7/8-1B 389 396

10/15/85 FE-7ABC FE-7/8-1B 541 556

10/16/85 FE-7ABC FE-7/8-1B

10/17/85 FE-7ABC FE-7/8-1B

08/15/84 FE-7ABC FE-7/8-2A

09/20/84 FE-7ABC FE-7/8-2A

09/20/84 FE-7ABC FE-7/8-2A 585 585

557 562 6

563 568 6

356 367 12

581 584 4

8 data recording

error - #2 nozzle

static pressure low

(332 psig) , data

channel voltage

values all low

relative to the

other operating

nozzles

16 CEESI/NBS

investigation

of data acquisition &

instrumentation syst.

*temperature data

recording error

1 operating program

abort

08/15/84

08/20/84

09/25/85

09/25/85

FE-7ABC FE-7/8-2B

FE-7ABC FE-7/8-2B

FE-7ABC FE-7/8-2B

FE-7ABC FE-7/8-2B

09/26/85 FE-7ABC FE-7/8-2B

09/27/85 FE-7ABC FE-7/8-2B

10/30/85 FE-7ABC FE-7/8-2B

10/30/85 FE-7ABC FE-7/8-2B

368 373 6 * 392 403 12 * 429 431 3 system error

421 435 15 CEESI monitored

diagnostic tests

440 459 20 CEESI monitored

diagnostic tests

464 467 4 thermometer connected

incorrectly

687 687 1 system error

691 691 1 system error

08/07/84

08/08/84

08/09/84

08/10/84

09/30/85

09/30/85

FE-7ABC FE- FE-7ABC FE- FE-7ABC FE- FE-7ABC FE- FE-7ABC FE- FE-7ABC FE7/8-3A

7/8 -3A

7/8-3A

7/8 -3A

7/8-3A

7/8-3A

260

272

296

320

487

496

271

295

307

331

487

496

12

24

12

12

1

1

**

system error

system error

108
Table 27. Inventory of observation runs -- Continued

Deleted Runs

Date Meter Orifice Run No, Num. of Comments

Tube Plate Beg. End Runs

08/03/84 FE-7ABC FE-7/8-4A 170 175 6 nozzle 2 static

pressure data

input channel

error, pressure

value 80 psi below

other nozzle

plenum pressures

08/03/84 FE-7ABC FE-7/8-4A 188 205 18 * 09/26/84 FE-7ABC FE-7/8-4A 642 643 2 power failure at

the test site

08/06/84 FE-7ABC FE-7/8-4B 218 235 18 *

07/13/84 FE--7ABC FE-7/8-5A 52 57 6 * 07/15/84 FE-7ABC FE-7/8-5A 58 64 7 + 07/19/84 FE-7ABC FE-7/8-5A 71 76 6 * 07/20/84 FE-7ABC FE-7/8-5A 77 84 7 * 07/25/84 FE-7ABC FE-7/8-5A 97 97 1 + 09/27/84 FE-7ABC FE-7/8-5A 652 671 20 operator indicates

07/26/84 FE-7ABC FE-7/8-5B

07/27/84 FE-7ABC FE-7/8-5B

07/05/84 FE-7ABC FE-7/8-6A

07/06/84 FE-7ABC FE-7/8-6A

07/31/84 FE-7ABC FE-7/8-6B

10/17/85 FE-7ABC FE-7/8-6B

10/18/85 FE-7ABC FE-7/8-6B

10/21/85 FE-7ABC FE-7/8-6B

10/18/85 FE-7ABC FE-7/8-6B

09/25/85 FE-7ABC FE-7/8-7B

09/18/84 FE-7ABC FE-7/8-7B

bad orifice pressure

readings

122 127 6 *

128 139 12 *

13 18 6 *

19 36 18 *

152 169 18 * 569 574 6 jCEESI/NBS investi575 593 19 Igation of data

1 acquisition instru1 mentation

594 597 4 incorrect nozzle

designation entry

583 585 3 chromatograph timing

cycle exceeded

436 439 4 CEESI monitored

diagnostic tests

579 580 2 temperature data

recording error

109
Table 27. Inventory of observation runs -- Continued

Date Meter Orifice Run No. Num. of Tot

Tube Plate Beg. End Runs Run

11/18/85 PE-8ABC FE-7/8-1B 864 884 20 20

11/12/85 PE-8ABC FE-7/8-2B 822 845 24

11/15/85 PE-8ABC FE-7/8-2B 848 863 16 40

11/11/85 PE-8ABC FE-7/8-3A 802 821 20

11/21/85 PE-8ABC FE-7/8-3A 913 932 20 40

11/07/85 PE-8ABC FE-7/8-4B 780 801 21 21

11/05/85 PE-8ABC FE-7/8-5B 740 759 20 20

11/06/85 PE-8ABC FE-7/8-6B 760 779 20 20

11/19/85 PE-8ABG FE-7/8-8B 889 908 20 20

Date Meter

Tube

Orifice

Plate

11/18/85 PE-8ABC FE-7/8-1B

11/15/85 PE-8ABC FE-7/8-2B

11/21/85 PE-8ABC FE-7/8-3A

11/07/85 PE-8ABC FE-7/8-4B

11/19/85 PE-8ABC FE-7/8-8B

Total Test Runs 181

Deleted Runs

Run No. Num. of

Beg. End Runs

Comments

872

846

909

785

885

872

847

912

785

888

1 chromatograph timing

cycle exceeded

2 chromatograph timing

cycle exceeded

4 valve partially

closed during plate

change

1 system error

4 operator indicates

a small leak

around an indicating

gauge stem

110
Table 27. Inventory of observation runs --- Continued

Date Meter Orifice Run No. Num. of Total

Tube Plate Beg. End Runs Runs

08/21/85 FE-9ABC FE-9/0-1B 230 247 16

08/22/85 FE-9ABC FE-9/0-1B 248 258 10

08/23/85 FE-9ABC FE-9/0-1B 260 267 8

08/26/85 FE-9ABC FE-9/0-1B 270 277 8

08/27/85 FE-9ABC FE-9/0-1B 279 282 4 46

08/08/85 FE-9ABC FE-9/0-2A 114 125 12

08/09/85 FE-9ABC FE-9/0-2A 126 137 12

09/04/85 FE-9ABC FE-9/0-2A 357 372 16 40

08/02/85 FE-9ABC FE-9/0-2B 34 57 24 24

07/30/85 FE-9ABC FE-9/0-3B 1 8 8

07/31/85 FE-9ABC FE-9/0-3B 9 25 16

08/01/85 FE-9ABC FE-9/0-3B 26 33 8

08/30/85 FE-9ABC FE-9/0-3B 330 345 15

09/03/85 FE-9ABC FE-9/0-3B 346 356 8 55

08/09/85 FE-9ABC FE-9/0-4A 138 149 12

08/12/85 FE-9ABC FE-9/0-4A 150 153 4

08/14/85 FE-9ABC FE-9/0-4A 182 193 12 28

08/05/85 FE-9ABC FE-9/0-4B 58 73 12

08/14/85 FE-9ABC FE-9/0-4B 194 201 8 20

08/06/85 FE-9ABC FE-9/0-5B 74 85 12

08/15/85 FE-9ABC FE-9/0-5B 202 213 12 24

08/12/85 FE-9ABC FE-9/0-6A 154 161 8

08/13/85 FE-9ABC FE-9/0-6A 162 173 8

08/19/85 FE-9ABC FE-9/0-6A 222 229 8 24

08/08/85 FE-9ABC FE-9/0-6B 102 113 8

08/13/85 FE-9ABC FE-9/0-6B 174 181 8

08/19/85 FE-9ABC FE-9/0-6B 214 221 7 23

08/27/85 FE-9ABC FE-9/0-7B 283 286 4

08/29/85 FE-9ABC FE-9/0-7B 310 325 16

08/30/85 FE-9ABC FE-9/0-7B 326 329 4 24

Total Test Runs 308

ill
Table 27. Inventory of observation runs -- Continued

Deleted Runs

Date Meter Orifice Run No. Num. of Comments

Tube Plate Beg. End Runs

08/21/85 FE-9ABC FE-9/0-1B 242 243 2 data lost d

08/22/85 FE-9ABC FE-9/0-1B 254 254

08/22/85 FE-9ABC FE-9/0-1B 259 259

08/26/85 FE-9ABC FE-9/0-1B 268 269

08/27/85 FE-9ABC FE-9/0-1B 278 278

07/31/85 FE-9ABC FE-9/0-3B

08/30/85 FE-9ABC FE-9/0-3B

09/03/85 FE-9ABC FE-9/0-3B

07/25/85 FE-9ABC FE-9/0-3B

08/05/85 FE-9ABC FE-9/0-4B

21

335

350

971

21

335

352

974

62 65

08/13/85 FE-9ABC FE-9/0-6A 166 169

conflict with

chromatograph print

cycle

1 data lost due to

conflict with

chromatograph

operating cycle

1 operator abort - incorrect PRT

connection

2 error in recording

transducer coeff.

file

1 system error

1 system error

1 chromatograph timing

cycle exceeded

3 system error

4 initial four system

test done at the

beginning of the

1985 data collection

period. Run

numbers set to 971 - 974 in anticipation

of not using them in

normal test runs.

4 pressure transducer

not properly zeroed.

4 Incorrect nozzle

deslg. entered

112
Table 27. Inventory of observation runs -- Continued

Deleted Runs

Date Meter Orifice Run No. Num. of Comments

Tube Plate Beg. End Runs

08/06/85 FE-9ABC FE-9/0-6B 86 93

08/07/85 FE-9ABC FE-9/0-6B 94 101

08/08/85 FE-9ABC FE-9/0-6B 106 109

08/19/85 FE-9ABC FE-9/0-6B 217 217

08/28/85 FE-9ABC FE-9/0-7B 299 299 1 08/29/85 FE-9ABC FE-9/0-7B 308 309 2 08/28/85 FE-9ABC FE-9/0-7B 287 307 21

orifice plate not

concentric with the

meter tube

orifice plate not

concentric

with the meter tube

valve on #1 up

stream pressure

transducer closed

low orifice static

pressure

nozzle desig. error system error

FE-9/0-5A orifice

plate installed

upstream of the

meter run

113
Table 27 . Inventory of observation runs - - Cont inued

Date Meter Orifice Run No. Nxoin. of Total

Tube Plate Beg. End Runs Runs

11/07/84 FE-OABC FE-9/0-1A 915 922 8

11/15/84 FE-OABC FE-9/0-1A 955 958 4 12

11/15/84 FE-OABC FE-9/0-1B 959 962 4 4

10/18/84 FE-OABC FE-9/0-2A 795 810 16 16

10/19/84 FE-OABC FE-9/0-2B 811 822 12 12

10/15/84 FE-OABC FE-9/0-3A 735 754 20 20

10/12/84 FE-OABC FE-9/0-3B 712 734 20 20

10/16/84 FE-OABC FE-9/0-4A 755 774 20 20

10/17/84 FE-OABC FE-9/0-4B 775 794 20 20

10/22/84 FE-OABC FE-9/0-5A 827 838 12

10/30/84 FE-OABC FE-9/0-5A 899 906 8 20

10/23/84 FE-OABC FE-9/0-5B 839 850 12

10/30/84 FE-OABC FE-9/0-5B 891 898 8 20

10/24/84 FE-OABC FE-9/0-6A 851 858 8

10/29/84 FE-OABC FE-9/0-6A 879 890 12 20

10/24/84 FE-OABC FE-9/0-6B 859 866 8

10/26/84 FE-OABC FE-9/0-6B 867 878 12 20

Total Test Runs 204

114
Table 27. Inventory of observation runs -- Continued

Deleted Runs

Date Meter Orifice Run No. Num. of Comments

Tube Plate Beg. End Runs

11/08/84 FE--OABC FE--9/0-lA 923 930 8 diff. pressure

pulsations

11/08/84 FE--OABC FE--9/0--IB 931 946 16 of approx. 4 in.

11/09/84 FE--OABC FE--9/0--IB 947 950 4 of water pulsations

11/09/84 FE--OABC FE--9/0--lA 951 954 4 obs. by operating

personnel

11/06/84 FE--OABC FE--9/0--2A 907 910 4 transducer

malfunction

11/16/84 FE--OABC FE--9/0--2A 963 966 4 bad static pressure

calibration

11/06/84 FE--OABC FE--9/0--2B 911 914 4 bad static pressure

11/16/84 FE--OABC FE--9/0--2B 967 970 4 calibration

10/19/84 FE--OABC FE--9/0--2B 823- 826 These test runs were

recorded incorrectly

and could not be

properly analyzed.

10/12/84 FE--OABC FE--9/0--3B 724 726 4 data lost - conflict

with chromatograph

print cycle

115
C. Presentation of the Data Analysis Results

The results of the test run data analysis are presented in tabular and

graphical form. Tabulation for each test run is limited to a single

line. Computation of discharge coefficients or Reynolds number from the

values listed for each test run is not possible due to the finite extent

of the tables and the number of intermediate parameters necessary to do

so. Those interested in a greater level of analytical detail may

consult the archival database which contains all of the observed data.

Four sets of data tables are ordered by meter tube and orifice plate.

Tables 28 - 31 tabulate the results for each meter tube tested with each

orifice plate's results contained in a table subsection. The tables are ordered according to the meter designation, i.e., beginning with the

6-inch mild steel meter tube, FE-7ABC, in table 28, and ending with the

second 10-inch meter tube, FE-OABC. The electroless nickel-plated, 6-

inch mild steel meter tube is designated PE-8ABC, and its test run results are given in table 29. The measured diameter values for the

m.eter tube and plate and the resulting beta ratio are listed in the

heading for each page of the table. The contents of the table's columns

are the following:

Run No.

Date

Orifice Temp,

Orifice Press.

Orifice Density

Differential

Pressure

Mean

Std. Dev.

Mass Flow Rate

Total

Rand.

Test run number.

Observation date.

Temperature of the flowing fluid observed

approximately five diameters from the orifice

union.

Orifice absolute pressure observed at the downstream orifice tap (psia)

.

Density of the natural gas computed for the

orifice temperature, pressure, and composition

conditions

.

Average of the means of the observed values for

the high or low range transducer set. The set

selected is that appropriate to the differential

pressure, i.e., for differential pressures below

40 inches of water, the low range transducer

values were selected. For differential pressures

above that, the high range transducer values were

selected. The values given in parenthesis are given in pressure units of inches of water at

4 "C. The values give in the second column are given in pressure units of pounds per square inch

(psi).

The pooled standard deviation of the mean values

of the two observation sets in pressure units of

psi. Three standard deviations are used in the

pooling.

The total mass flow rate computed for the

nozzles in use. The random error component derived from the

116
Syst.

Coefficients

Mean

Rand.

propagation of errors analysis.

The larger of the systematic error components

including estimated effects of throat temperature

differences between calibration and use conditions

Average discharge coefficient values obtained from

the corresponding differential pressure

measurement

Random uncertainty in the discharge coefficient

value taken from the propagation of errors

analysis. This is the pooled estimate obtained

from the mean of the random uncertainties computed

from the two arrays of differential pressure

observations (three standard deviation value)

The pooled estimate is obtained from the mean of + St the two variances , i.e., s (- 1/2 where

Syst,

s^ and S2 are the absolute uncertainties derived

from each differential pressure transducer's array

of response data.

The systematic uncertainty in the discharge

coefficient value taken from the propagation of errors analysis using the larger of the two

systematic uncertainties in mass flow rate. The

value given is the mean value

Reynolds Number - Pipe Reynolds number based on the meter diameter.

Gas and Nozzle

Number

Throat Pressure

and Temperature

Gas type is indicated in the first column with an

"A" for Amarillo gas, i.e., approximately 90 mole

percent methane concentration or a "G" for Gulf

Coast gas having approximately 95 percent methane

concentration

The number of nozzles in operation is given in the

second column.

The average values computed for the nozzle throat

pressure and temperature.

The results of the analysis are also plotted for each orifice plate.

The plots are placed after the table section for each meter tube and are ordered sequentially by beta ratio. The following subsections contain

plots and tabulations for each meter tube and orifice plate.

117
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118
1

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Press.

Temp.

(Psia)

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0) ^ sO «- CO to K s* in CO ss to s* st st in CM st CM to |N-

>»• •- 10 CO N* in to <\i to t>- o> On O fVJ sj On vt (^ to O 1-^ fM

CM

::: s CO >* m \D is! f to f to in in vd nO d d ^ rl in no no r-^ «) >0 O Q. a. f\J f\J f\J IM

S.IS. r^N.

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H- II IS. to <o o >0 <0 to in fj^sa <0 to IN. o> in to o o

I.

i

.'-^ to t^ O r^ to s* On CO NO st st «- o> t^

l- O ^fSlilS ^

in ir CO oc in

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0> s^ »X -v. ^ ^ ^ ^ ^ ^"s, V. s^ ^ ^ ^ ~«s S» >» "SS N-S u A) o o o o c o a O O C o o a O o o o o o o

•^ a •>,>.>>.>». >» »«s ^ "s. ^ -Sh s., ^ ss. ^ S^ ^ S.. NS. >S> NS,

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Of 2

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ts. rs. r^ rs. PiPifCfC PfCfCR KPCfC

143
Meter Tube FE-7ABC

0.605

o

w 0.600

0.595

0.590

-

t*

FE-7/8-8B

Beta = 0.10286

* 11/01/85

-

: t

-

*

1 1 1 1 1 1 1

1

1 1 1 1 1 1 1 1 1

1 10 10 10

Figure lOA. Discharge coefficient/Reynolds number plots,

FE-7ABC, 6-inch meter tube, 15 orifice plates,

144
Meter Tube FE-7ABC

u.ouo ^ '- O

Q) 0.600 - \

§

FE-7/8-8A

Beta = 0.20630

o 09/12/84

X 09/13/84

0.595 -

O

n izon

oo

o

8

i — M— — — —

U.OHU 1 1 1 1 1 1 1 1

1

1 1 1 1 1 1 1 1 10' 10 10

Stolz Buckingham

0.610

& 0.605 H

FE-7/8-1B

Beta = 0.20618

o 09/10/84

09/1 1/84

09/12/84

X 09/23/85

+ 10/07/85

o 10/31/85

Pipe Reynolds Number

Figure lOB. Discharge coefficient/Reynolds number plots,

FE-7ABC, 6-lnch meter tube, 15 orifice plates

145
Meter Tube FE-7ABC

^ 0.605 -

o

r

g 0.600

I

0.595

10

"1

1 I I I r 10

FE-7/8-2A

Beta = 0.37125

o 08/15/84

09/20/84

09/21/84

-\ 1 1—I—I—TT-r

10

Stolz Buckingham

0.604

5 0.599

•g 0.594

.^ 0.589

0.584

_______^

FE-7/8-2B

Beta = 0.37123

o 08/16/84

08/20/84

* 09/24/85

X 09/27/85

+ 10/30/85

0- -fl -

*

X

X

1 1 I 1 1 1 1 1 1

1 1 1 1 1 1 1 1 /o

Pipe Reynolds Number

10

Figure IOC. Discharge coefficient/Reynolds number plots,

FE-7ABC, 6 -inch meter tube, 15 orifice plates

146
Meter Tube FE-7ABC

U.O 1 u —

/-^-r/fi-s^

4?

O

c» 0.605 - r - B

t ^ *

5eta = 0.49505

o 08/07/84

08/10/84

* 09/30/85

X 10/01/85

^ 10/29/85

1 - 0.600 -

#+

+

U.OirO 1 1 1 1 1 1 1 1

1

I 1 1 1 1 1 1 1 /o /o /o

Stolz Buckingham

0.610

O

I

g 0.605

00

0.600

10

FE-7/8-3B

Beta = 0.49507

o 08/13/84

09/24/84

T 1 1—I I I I

I

1 1 1

1—I I I I 10^ 10'

Pipe Reynolds Number

Figure lOD. Discharge coefficient/Reynolds number plots,

FE-7ABC, 6-inch meter tube, 15 orifice plates

147
Meter Tube FE-7ABC

§ -

^ 607 —

e

J•

* #

FE-7/8-4A

Beta - 0.57724

o 08/03/84

08/13/84

* 09/26/84

U.OU/6 1 III 1 1 1 1 10 10

Stolz -Buckingham

10

. 0.607 -

5

e «

FE-7/8-4B

Beta = 0.57748

o 08/06/84

10/01/85

* 10/25/85

?» 0.603 - 1 -

0) 0.599 - 1 :

a

* *

*

t

t

t/.OaO. 1 III 1 1 1 1 Pipe Reynolds Number

10

Figure lOE. Discharge coefficient/Reynolds number plots,

FE-7ABC, 6-lnch meter tulje , 15 orifice plates

148
Meter Tube FE-7ABC

o

u.oio —

0.608 -

i

g«5

FE-7/8-5A

Beta = 0.65995

o 07/09/84

X 07/23/84

+ 07/25/84

o 09/25/84

^ 09/28/84

#

— .

0.603 - 1 III 1 1 1 1 10 10

Stolz Buckingham

O

u.o 1 a FE-7/8-5B

Beta = 0.66003

9

o 07/26/84

10/24/85

0.605 -

-

~ ^^~

n TQ^

a

°

n B a

u.oao 1 1 1 1 1 1 1 10

Pipe Reynolds Number

10'

Figure lOF. Discharge coefficient/Reynolds number plots,

FE-7ABC, 6-inch meter tube, 15 orifice plates

149
Meter Tube FE-7ABC

^ 0.610 -

f

- s D

FE-7/8-6A

Beta = 0.74237

o 07/03/84

07/05/84

10/01/84

X 10/03/84

+ 10/22/85

5

t

% « ^ 0.600 -

Q> -

, . + + +

U.OiiU 1 1 1 1 ! 1 1

1 /o /o

Stolz Buckingham

g 0.6/0 -

r :

«

FE-7/8-6B

Beta = 0.74245

o 07/31/84

10/08/85

^ 10/10/85

X 10/21/85

1

;| 0.600 -

M X n

U.oaU 1 1 1 1 1 1 1 /o

Pipe Reynolds Number

10

Figure lOG. Discharge coefficient/Reynolds number plots,

FE-7ABC, 6-inch meter tube, 15 orifice plates

150
Meter Tube FE-7ABC

§ 0.598

0.590

10*

Stolz Buckingham

10'

u.ouu —

O

r -

•g 0.595 -

o

s

FE-7/8-7B

Beta = 0.10319

o 09/17/84

09/18/84

* 09/16/85

X 09/17/85

o

o

o

§

*

*

*

8

o

o

D D

D

Orifice

Dis

1

1

1

1

V.\J%7V 1 1 1 1 1 1 III 1 1 1 1 1 1 1 1 10' 10'

Pipe Reynolds Number

Figure lOH. Discharge coefficient/Reynolds ntomber plots,

FE-7ABC, 6-inch meter tube, 15 orifice plates,

151
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160
Meter Tube PE-8ABC

u.ouu — FE-7/8-1B

Beta = 0.20543

O / 1/18/85

Cj

03 0.596 - J i

0.592 -

1 :

8

__!_

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0.605

O

Co

Q) 0.600

I

CO

0.595

0.590

10'

Pipe Reynolds Number

Figure llA. Discharge coefficient/Reynolds niimber plots, PE-8ABC,

6 -inch meter tube, 7 orifice plates.

161
Meter Tube PE-8ABC

Orifice

Discharge

Coeff.

><

05

05

1

1

1

1

1

1

1

1

1

1

1

1

1

1

-^

B

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• FE-7/8-3A

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/ /// 1/85

u 11/21/85

^1

m

u.\ja\j 1 1 1 1 1 1 1 1

1

1 1 1 1 1 1 1 1

1 10 10 10

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10

FE-7/8-4B

§ 0.606 -

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11/07/85

Q)r -

j;^ 0.602 - § « 9

ft

U.Oao 1 1 1 1 1 1 1 Pipe Reynolds Number

10'

Figure IIB. Discharge coefficient/Re3molds number plots, PE-8ABC,

6-inch meter tube, 7 orifice plates.

162
Meter Tube PE-8ABC

o^ 0.605 - — -

§

FE-7/8-5B

Beta = 0.65761

o 1 1/05/85

1—

'_

(U

o^ 0.601 -

8 S

s

U.Dif / 1 1 1 1 1 1 i 10 10

Stolz Buckingham

o^ 605 -

~~~-

8

FE-7/8-6B

Beta = 0.73973

o / 1/06/85

1 - ^ 0.601 -

8

n ^Q"?* U.Oa 1 1 1 1 1 1 1 1 10

Pipe Reynolds Number

10

Figure IIC. Discharge coefficient/Reynolds number plots, PE-8ABC,

6-iTich meter tube, 7 orifice plates.

163
Meter Tube PE-8ABC

§ 0.598

I

^ 0.594

0.590

10'

o

-Oo

8 e§

o

o §

n I 1 I I I I

FE-7/8-8B

Beta = 0.10248

o 11/19/85

I I ri

10'

Pipe Reynolds Number

10

Figure IID. Discharge coefficient/Reynolds number plots, PE-8ABC,

6-inch meter tube, 7 orifice plates.

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g *J U 1 (A o o «~ o o o o o o o o o o o o o .- O o o o o (^ C c • a o o o o o o o o o o o o o o o o O O o o o o o o « • •o s.^ • • • • • • • (0 J o o d o o d d d d d d d d d d o o o o o o o o o o m 41

(-

(/> H- 1 ro «- ^ o in in Pn. CO K

CO o vj- ro On lO CO ,_ s- On ro ro «^ On t^ rN«. H- (> o. c ^N O CO H 28 

R

On r«- ro CO CO ^— in in in

m 00 CO ro On inm NO

O (0 «»- O- 00 ^ 1 in

m in in rvj CO CO CO ^ nO nO nO o o O Onm >* ro CO o o • 0) S5 ^ ^ >» ^ ^ ^

r.. |Nw hw t>>. CO CO 00 00 >* >* >» ro ^ * N* xt o <*- z o. • • • • • • t • • •

«>

II <«- N-/ fs. r^ rw fv.

dddd o o o o *" *" «" *" ro ro ro ro inm inm

Vi a ^N CO o <o

K cccc o o o o cccc in >* ro CO ^% <^ ^-S ^N

CO On nO st I c ii CO OO rvj CO CO (^ d d o o ^ ,_ ,_ ,_ >* vt >* •* T— o o o u o> Ov CO (\i CO CO in m tn in On On On On in in m in

(0 <0 ^^ «- «- «— T— «~ io o

\^ ^^ Vi^ ^^ v^ >^

v 0*

X *^ o u 1 4-> u. r^ ro o> ro !». CO »- s • »- CO CO v» On ro CO o 00 in -*N- T"

O NO f" • ^ 1 *^ u fM ^ ^— CO m CO On O On

ui NO r^ fNw ro N* in no »- On r* in o ^3 CM On <- H- 1 (A V. o * 3

N- o On On On On On O- On On On nQ in

o3 00 in in Ong o8 N. • ^ F* 1 C Ji 00 o3 00 On On CO 00 00 CO CO 00 CO CO CO CO CO CO CO 00 c C 1 ^j • a R « • • o o I a ^ *" *" '" *" '" *" "" '" *" *" *" *" *" *" *" *" r- ^ *" *" *" *" *" *"

-»

u , ^^ ro o <o 00 On On^ ro nO ro o s

CO nO N* 1^ CO in vt to m CO ro K> ro o o> CO o • ^ tA <D CO N- ro o NO fo On O N- ^ m On «> ro in o ^ CO in ro H- (A •V • t • • • • • •^ 01 (A in vj- v^ -* %

00 to- r^ N> CO 00 CO h- CO OO 00 hJ NO nO in t^ NO in >»

0* L.

C O. o c> o> C> On On On On On On On On On On On eo CO 00 CO On

O On t^ 2 o a. ^^ in in m m in in m m m m in m m in m u-» in m m m m m m m ^ CO ro CO C> CO CJ CO CO Nt CO ^ ^ ^ CO o ^

RiS On r^ o e\i in o

g-

*-* r>. eo

m »- NO r«- 1^ in «- »- o o o nO nO nO CO On CJ s o <p r^I CO t

nO NO nO nO fsl fN-I nI r^ n! r*^ nI NO NO nO nO nO r>! fN^ r^ CO

1— ^ o^ o o> On On On On On On On 0> On On On On On On On On On On On On

in in in in in in in in

m in in in in in in in in in inm tn in in tn

CO OO CO CO 00 CO OO OO 00 OO OO eo 00 OO CO CO OO OO 00 eo CO CO CO CO o ^ >>> »v ^ -». "^ >- v — ^ ~». •^ •«^ >v »>» ^ »x ^ >>» N«> **

*N. »^ •»> ^ N. r^ r^ r- On On On On On On On On On On On On On On On On O o o o (0 CO CO CO CO CO CO CO CO CO CO CO CO CO CO CJ CO CJ CO CO CO ro ro ro ro o *>*>» »^ »»» "v '^^ -^ •^ ^ ^ ^ •n^ "^ >>> ^ ^ ^ ^ -N» «•» N>« «•.. -N* >»

00 CO CO 00 OO OO OO OO OO CO CO CO CO CO OO CO CO CO 00 CO 00 CO CO CO o o o o o o o o o o o o o o o o o o o o o o o o c , sss

in s o «- CO ro >*

m NO r^ OO OnO ,_ CO ro >«• in NO r^ OO On 3 o OO CJ CO CO CO CO rvj CJ CJ rsj CO

oe z CO CO CO CO lO ro ro ro ro ro ro ro ro ro ro ro ro ro ro ro ro ro ro ro

177
Meter Tube FE-9ABC

u.ouo § - a : a 0.600 -

1 1

i

FE-9/0-7B

Beta = 0.09913

o 08/27/85

o 08/29/85

08/30/85

1

0.595 - 1 -

B •

\ \

^ — -_ __

i

U.OifU 1 1 1 1 1 1 III 1 1 1 1 1 1 1 1

1 10' 10'

Pipe Reynolds Number — Stolz Buckingham

10

10 ' Pipe Reynolds Number

Figure 12A. Discharge coefficient/Reynolds number plots, FE-9ABC,

10-lnch meter tube, 10 orifice plates.

178
Meter Tube FE-9ABC

u.ouo

O

,__^^

FE-9/0-2A

Beta = 0.37 f 72

o 08/08/85

08/09/85

* 09/04/85

r -

•g 0.600 - %iaa

•5 ° §

o

U.OifO 1 1 1 1 1 1 II 1

1 1 1 1 1 1 1 1 1 10 10 10

Stolz Buckingham

10

u.ouo FE-9/0-2B

Beta = 0.37172

&5 =^^^___

o 08/02/85

"^ GOO — ^ «c

s_ _ _ _ _

1 -

n tratr

O

8

U.OiftJ 1 1 1 1 1 1 II 1

1 1 1 1 1 1 1 1 10 ' Pipe Reynolds Number

10

Figure 12B. Discharge coefficient/Reynolds number plots, FE-9ABC,

10-inch meter tube, 10 orifice plates.

179
Meter Tube FE-9ABC

0.608

FE-9/0-3B

Beta = 0.49565

o 07/30/85

07/31/85

* 08/01/85

X 08/30/85

+ 09/03/85

Pipe Reynolds Number — Stolz Buckingham

10

FE-9/0-5B

s

'—-__ Beta = 0.65694

'K ^ «, S^

o —

;j ~— — o 08/06/85

Q) 08/15/85

&5 602 —

ti 4S

d

e

5 e

c^ o

o .''

s

e

U.Oai 1 1 III 1 1 1

1

1 1 1 1 1 1 1 1 fO'

Pipe Reynolds Number

10

Figure 12C. Discharge coefficient/Reynolds number plots, FE-9ABC,

10-inch meter tube, 10 orifice plates.

180
Meter Tube FE-9ABC

0.608

O

(»I

-g 0.604

O

I

0.600

-

FE-9/0-4A

Beta = 0.57015

o 08/09/85

n 08/12/85

* 08/14/85

— ——

-

§

8 g B

*

#

*

1 III 1 1 1 1 1 10 10

Stolz Buckingham

0.608

o

r

•g 0.604

«^U

I

0.600

10

FE-9/0-4B

Beta = 0.57015

o 08/05/85

n 08/14/85

-___— — — __

o

u

B

1 1 1 1 1 1 1 1 Pipe Reynolds Number

10

Figure 12D. Discharge coefficient/Reynolds number plots, FE-9ABC,

10-inch meter tube, 10 orifice plates.

181
Meter Tube FE-9ABC

u.ouu —

„___^_^^ FE-9/0-6A

or

~~ ~o

"§-

Beta = 0.74379

o 08/12/85

08/13/85

^ 09/19/85

O

1

•g 0.595 - 2

0) 1 -

n /zon

D i M ° * #

U.oHU 1 ill! 1 I I

1

1 1 1 1 1 1 1 1 10 10 10

0.600

o

I

•< 0.595

0.590

10

Stolz Buckingham

FE~9/0-6B

Beta = 0.74380

o 08/27/85

08/29/85

08/30/85

§

i 8 t

1 1 1—I—I I I I 1—I—r~T

10 10

Pipe Reynolds Number

Figure 12E. Discharge coefficient/Reynolds number plots, FE-9ABC,

10- inch meter tube, 10 orifice plates.

182
1 t o in

M (M t\j in in to to eo to N- to

4-> 5

(0 1-

w

O

CO CO CO CO <0 >o >o >o to to pJ pJ

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•^ • • f\j rj ro fM »-«-«-»- to to to to

in E n

ra 3 o u u z z u

u

uu o o cr o o o o o s >. T- M >o »- t^ o vt to o r^ T- to o O I. in in ^ -* >j- o vj- o •O h^ >* in

a: 0) »-•«»• t>~ o <M to o «- in to (NJ «-

LU « ^ « «

u. S.I

»-

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•- z

a.

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(U

u f>j rj f\j (\j r\j f\j f\j i\i PO PO IM <\l jj II . (0 o o o o o o o o o o o o

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C£ (DOC roMM fO to to to to PkJ PJ to PJ

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m ^ — (D o o o o o o o o o o o o +-» 4-> U H- Q£ I I • • • • • • ^ o to *- o o o o o o o o o o o o 3 CD .^ (U O O O r^ ro >o -* <0 in m vO in «- o f\j «- Ov in o z ^ O C 'O ^ ^ in r- T- T- O U) 01 O^ Ov 0» O' o- o« O O^ 0> On O On < 0) 1 O in in in in in in in m m in m m f z I I • • • ( • 1 u o o o o o o o o o o o o o c

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m CO p> o o o I • ^ .- ^ o m in in in (N- t^ CO 00

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a> I. ^ >* -^ vf o o o o o V li. (0 to o o o o <r- <r- r— ^- o o o o •M to""-? o o o o O O O O o o o o >«- •^ to 3 o o o o O O O O o o o o I- (0 o o^ ^^§ oj r^ o o

7681 7208 6479 5964 CO «- 1^ to

1. (0 fO N- N- CO «- eo NO CO o ^ 1 4-1 0> in «- «- «- o o o H- o CO CO CO ^- t^ tNw r^ r.. 3 1— >t -dr >» >* (VI <M (\J CM 0> On On On

(A *- • I • 3

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t.

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ra 4-> 1 • • • I c i c d d d Ch o d o> 0> 00 00 00 00 u tVJ <M (\J »- in m «* ^ (fl a : ^ oo o >>^ u u • 4^ U. ^ s- ro eo O^ On in o nO to to N- • ^ ^ • .,- o ^ vo «- r^ t>^ to N- to tO PnJ «- O >4- »^ • to v^ in >* •* (\j (\J IM «- «- in in in m •^ < C Si O o o> o> CO CO CO CO On C> O On

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m >»- to •-

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<o t>^ si hJ

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183
f o o >o >* ro I CL ^^ £ u. (^ «^ «**- V*

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to O) (U . <> o >o rvj cn (DOC (M (M M ro 8 o o o o <Q ^ •- <D o o o o 'M M o M- q; • c 0) (fl -4- o o o o 3 CO .— 0) o Ci O in «- r<^ M ac ^ o c

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J= • z • • 1 U o o o o O c

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co - = O

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1 o ro ro •.* vi- ~* c^ |N- -* t^- On «^ CM CM CM CM to

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t_ (A — CM rvi c\j ru CM (M CM C\J CM CM CM CM CM CM CM CM

0) (0 M M ro M lO to to hO to to to to to to to ro

> c- a.

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<D 3 O U Z Z U U C9 U C3 O O O t3 13 C3 13 <3 CT t3 13 m

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UJ

u.

c\j CO o ro -* to o «- to 1^ in »* On O vO »-

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1— tn c o . \0 >o vO ^ to to to to -* vl- ^ vl- vO NO nO -O

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4-i II • CO o o o o o o o o o o o o O O O O

o . CO M

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194
Meter Tube FE-OABC

FE-9/0-1A

^^

Beta = 0.19936

o 1 1/07/84

u 1 1/15/84

o^ 0.596 -

a

8

8 - - i

1 :

^ 0.591 -

o

Orifice

D

1

1

1

1

n

U.xJOO 1 1 1 1 1 1 1 10 10

Stolz Buckingham

FE-9/0-1B

^^

Beta = 0.1994

11/15/84 o^ 0.596 - —

r

-

•5^ 0.591 -

Orifice

a

1

1

1

1

l/.UOO 1 1 1 1 1 1 1 10

Pipe Reynolds Number

10

Figure 13A, Discharge coefficient/Reynolds number plots, FE-OABC,

10-inch meter tube, 12 orifice plates.

195
Meter Tube FE-OABC

^ 0.604 - FE-9/0-2A

Beta = 0.37405

o 10/18/84

r : "^'^—~~

-*£ — — _- -^0

g 0.599 -

§

U.Oa4- 1 1 1 1 1 1 1

1

1

1 1 1 1 1 1 1 1 1 10 10 10

Stolz Buckingham

10

l/.OL/Q — FE-9/0-2B

o

Beta = 0.37405

o 10/19/84

1 - ^ 600 — "^^^——.___^_^

42

g —0— — — — —

ft) 1 -

§

u.oito 1 1 1 1 1 1 1 1

1

1 1 1 1 1 1 1 1 1 /O" 10'

Pipe Reynolds Number

Figure 13B. Discharge coefficient/Reynolds number plots, FE-OABC,

10-inch meter tube, 12 orifice plates.

196
Meter Tube FE-OABC

o

I

FE-9/0-3A

- Beta = 0.4988

0.604 -

— -- — —

o 10/15/84

— e §

8

8

f\ eroQ

O

§

U.Oifa 1 1 1 1 1 1 1 10 10

Stolz Buckingham

o

0.605 -

0.600

Pipe Reynolds Number

Figure 13C. Discharge coefficient/Reynolds number plots, FE-OABC,

10- inch meter tube, 12 orifice plates.

197
Meter Tube FE-OABC

o

— — _

8

FE-9/0-4A

Beta = 0.57373

o 10/16/84

§ 0.605 - 5

1 - §

8

8 8

U.OUl 1 1 1 1 1 1 1 10 10

Stolz Buckingham

0.608

o

-g 0.604

CO Ci

O

I

0.600

10

- FE-9/0-4B

Beta = 0.57373

o 10/17/84

-

— — -— — -

-

s

g

8 «

1 1 1 1 1 1 1 1 Pvpe Reynolds Number

10

Figure 13D. Discharge coefficient/Reynolds number plots, FE-OABC,

10-inch meter tube, 12 orifice plates.

198
Meter Tube FE-OABC

S 0.607

o

r

S 0.603

r

0.599

10

%

1 r I I I I I

I 10

FE-9/0-5A

Beta = 0.66109

o 10/22/84

D 10/30/84

1

1—1—I—I I I 10

Stolz Buckingham

O 0.606 -

- ^

o8

FE-9/0-5B

Beta = 0.66107

o 10/23/84

D 10/30/84

1 -

53 o

§

§ 0.602 -

o

1 - O . ^

U.OatS 1 1 III 1 1 1

1 1 1 1 1 1 1 1 1 10 10'

Pipe Reynolds Number

10

Figure 13E. Discharge coefficient/Reynolds number plots, FE-OABC,

10-inch meter tube, 12 orifice plates.

199
Meter Tube FE-OABC

^ 0.599 - /

8

FE-9/0-6A

Beta = 0.74846

o 10/24/84

D 10/29/84

o

r : % 0.594 -

1 :

D

U.ooa 1

1

1 1 1 1 1 1 1

1 1 1 1 1 1 II

10 10' 10

Stolz Buckingham

o

CO

jig 0.594

I

0.590

10

9

§ ii

1 1 1 I r 10

FE-9/0-6B

Beta = 0.74847

10/24/84

° 10/26/84

1—1—I I I I 10

Pipe Reynolds Number

Figure 13F. Discharge coefficient/Reynolds number plots, FE-OABC,

10-inch meter tube, 12 orifice plates.

200
D. Test Run Result Analysis and Discussion

The results of the test runs for the four meter tubes involved in these

tests are examined and compared for consistency. In doing so the

results of the propagation of error analysis are used as a guide to

evaluation of expected levels of scatter in the results. It should be

noted that the propagation of errors analysis treats those parameters

which are known to have an effect on the test results (see Appendix C

for a derivation of those parameters) . It is possible that other

sources of variability may effect the results which were not considered

in the propagation of error analysis. It is stressed that the following

is not a statistical analysis of the test results.

1. Discxission of Test Results - FE-7ABC

The FE-7ABC orifice meter tube and its associated orifice plates were

the first and second set of orifice meters to be tested during the 1984

and 1985 testing seasons, respectively. These orifice meters were the

only ones tested in both seasons. The following are brief comments and

observations on the character of the results. These are discussed in

ascending order of nominal beta ratio. References to Reynolds numbers

in the remainder of this discussion refers expressly to the pipe

Reynolds number.

Beta Ratio 0.1 - FE-7/8-7A & 7B

Test runs were performed on the 7A plate on one day in 1984. The

results of these test runs have a small level of scatter both within and

between test groups.

Plate 7B was tested in both 1984 and 1985. The data taken in 1984 agree

well with those taken on the lA plate. The 1985 data shows a con- siderable degree of scatter although it is still within the bounds of

the propagation of errors limits. Test runs 373 - 376 appear to have an unknown difficulty making the discharge values abnormally low (= 0.56).

Beta Ratio 0.2 - FE-7/8-8A & IB

The orifice plate marked FE-7/8-8A is a replacement plate for the

original plate marked FE-7/8-1A which was dished early in the program by

developing a very high differential pressure across it during initial

testing in the intermediate Reynolds number project [1]. The 8A plate

was only tested in 1984 at three flow rate settings. Discharge coefficient values for this plate agree well with the character of the C

values for the IB plate. The values for the IB plate show little

dependence on pipe Reynolds number. The scatter in the C values for

both plates has a band width of three-quarters to one percent with the

exception of test runs 397, taken in 1985, and 507 and 516, taken in

1984, which have an abnormally large variation in the differential

pressure and discharge coefficient values. These are offset from those

of the remainder of the test run group. The standard deviation of the

mean is approximately 5 times that of the other three runs taken in that

group

.

201
Beta Ratio 0.375 - FE-7/8-2A & 2B

The 2A plate was tested only in 1984. These test results have a level

of reproducibility of approximately 2 parts in 600 or 0.33% and fall

below the Buckingham and Stolz correlations by approximately the

magnitude of the average random uncertainty. Plate 2B was tested in

both 1984 and 1985. A small splitting in the results values may occur

at the lowest Reynolds numbers between the two years, but this is within

the random variation of the discharge coefficient values with the

exception of test runs 472 - 475 in 1985. These discharge coefficient

values are inconsistent with the remainder of the plate's results. This

fact was noted by the operator and the flow conditions were rerun the same day. The rerun test points are numbers 480 - 483 whose results are consistent with discharge coefficient values observed at other Reynolds

numbers

.

Beta Ratio 0.5 - FE-7/8-3A & 3B

The 3A plate was run in both operating years. The results from 1984 lie

above those obtained in 1985. The difference in C values for the two

years is larger than the random component of variation except at the

lowest pipe Reynolds numbers, i. e., differential pressures. The

difference between the two years results is approximately 4 parts in 600

or 0.66% or greater. The results of test runs 505-509 are not consistent with the remainder of the data on the 3A plate and have not been

plotted in the graph for that plate. The operator noted that Gulf Coast

gas was in use and that the regulators of the main pipeline were not in

service for these runs. The 1984 data taken on both plates is in good

agreement and has a between group variation of 1 to 2 parts in 600.

Beta Ratio 0.57 - FE-7/8-4A & 4B

Test runs on plate 4A were taken in the 1984 operating year only and are consistent with expected levels of variation from the propagation of

error analysis. Test run data were taken in both years for plate 4B.

However, only the two lowest differential pressure points are retained

in the final database due to zero drift in the high range differential

pressure transducer (see Appendix B) . The discharge coefficient values

for these two test groups, 206 - 217, agree well with those taken in

1984 on the 4A plate.

Beta Ratio 0.66 - FE-7/8-5A & 5B

Test runs on plate 5A were taken in 1984 only and are self consistent as

a set. Data were collected both before and after the change of differential pressure transducers in 1984. Discharge coefficient values

obtained on two days, one in 1984, the other in 1985, differ substantially between days. The difference is approximately 10 parts in 600

for the two lowest Reynolds nvimber points, which approximates the sum of

the random variations in the values. Even so this difference is large.

202
Beta Ratio 0.75 - FE-7/8-6A & 6B

Test runs were taken in both years on each plate. The 1984 and 1985

results differ substantially for a given plate, while results for the same year and plates of the same nominal beta ratio agree within the

variation predicted by the propagation of errors analysis.

2. Discussion of Test Results - PE-8ABC

The PE-8ABC meter tube was the only nickel-plated meter tube tested in

this project. These tests were performed as a check to determine

whether the nickel -plated meter tube surface caused any detectable

effects on orifice discharge coefficients. The B set of orifice plates

were tested at five flow rate settings each in a single series of tests

performed on one day with the exception of 2B and 3A which were replicated once. These tests were the last performed in November 1985. The

testing was stopped due to cold weather at the test site.

Beta Ratio 0.2 - FE-7/8-1B

The agreement with the results on this plate in the FE-7ABC meter tube

are good at the highest three pipe Reynolds number points. The discharge coefficient values obtained at the lowest differential pressure

points fall below those taken in the FE-7ABC meter tube, but are in

agreement due to the relatively large uncertainty of low differential

pressure measurement. Test runs 879 and 884 have considerably larger

random uncertainties in the differential pressure relative to the

remainder of the test runs on this plate.

Beta Ratio 0.375- FE-7/8-2B

Test runs were taken on two days with flow rates corresponding to 10,

45, and 100 inches of water repeated on the second day. Runs 830 - 833

fall below the remainder of the data. The operator noted this at the

time of the tests and repeated this flow rate setting at the end of the

day. The results of these reruns agreed more closely with those taken

at the other flow rate settings.

Comparison with the results obtained for this plate in the FE-7ABC meter

tube shows the low Reynolds number results in PE-8ABC to more closely

agree with the 1984 results in FE-7ABC than the 1985 values in the same meter tube. Generally the increasing trend of the discharge coefficient

value with pipe Reynolds number in 1985 is seen here except for the low

differential pressure values.

Beta Ratio 0.5 - FE-7/8-3A

Test runs were taken on two days over the complete flow rate setting

range of approximately 10 to 200 inches of water. The character of the

results is one of increasing discharge coefficient value with pipe

Reynolds number which is consistent with the behavior of the results

obtained on the 3A plate in FE-7ABC in 1985. The highest Reynolds

number results agree with the data taken on this plate in the FE-7ABC

meter tube in 1984. Generally the agreement between days, meter tubes

203
and years is within that expected from the propagation of errors analysis

.

Beta Ratio 0.57 - FE-7/8-4B

The reproducibility at each flow rate setting for these results is quite

good. Again the increase in discharge coefficient with pipe Reynolds

number is seen for this plate in both meter tubes in which it was tested

in 1985.

Beta Ratio 0.66 - FE-7/8-5B

The reproducibility of the results at each flow rate is smaller than

that of the between set values. However, the between set scatter in the

results is within the uncertainty predicted by the propagation of errors

analysis. The magnitude of the between setting variation seen with the

plate in PE-8ABC is not reflected in the FE-7ABC results which show

little dependence on Reynolds number and are approximately one percent

below the Stolz and Buckingham correlations.

Beta Ratio 0.75 - FE-7/8-6B

One day's tests were run with discharge coefficient values showing small

dependence on Reynolds number except for the lowest Reynolds number

group which lies near the outer bound of random variation as predicted

by the propagation of errors analysis. The results taken with this

plate in the FE-7ABC meter tube differ by approximately 6 parts in 600

which is at the outer limit of agreement predicted by the propagation of errors analysis.

3. Discussion of Test Results - FE-9ABC

Tests on the FE-9ABC meter tube were performed in 1985 only. The meter

tube had been refurbished which resulted in a very smooth meter tube.

Tests were performed on 10 of the 12 orifice plates. The results

observed for these plates agree within the propagation of errors analysis both internally and between plates. Both show a decrease in

discharge coefficient value at the high Reynolds numbers taken on the

Amarillo gas stream. However, the variation in the results is within

that predicted by the propagation of errors estimates.

Beta Ratio 0.2 - FE-9/0-1B

Discharge coefficient values for this plate show a good degree of

consistency with the exception of the test runs taken at pipe Reynolds

numbers between 200,000 and 300,000. The range of variation in the

values corresponds in most cases to larger differential pressure

variation than test runs taken at other Reynolds numbers. Test runs in

this Reynolds number range were repeated on several days. The last two

days of observations, August 26 and 27, 1985 were somewhat less scattered than the previous day's data, but still showed a larger degree of

204
variation than results taken at the other flow rate points. The variation seen in the Reynolds number range is consistent with the propagation of error analysis.

Many of those test points exhibiting large excursions from the characteristic variation band of discharge coefficient values also have

considerably larger variation in the mean differential pressure value,

particularly test runs 257, 253, 267, 264, and 247. Discharge coefficient values observed outside the 200,000 to 300,000 region show lower

within- group variation than predicted by the propagation of errors

analysis. This level of variation is also seen between Reynolds number

groupings which occupy a variation band of two to three parts in 600.

Generally, little dependence of the discharge coefficient values on pipe

Reynolds number is seen, although the lowest Reynolds number points may

exhibit a small dependency.

Beta Ratio 0.375 - FE-9/0-2A and 2B

Test runs were performed on one day on the 2B plate and three days on

the 2A plate. The results agree between the plates well within the

limits of the propagation of errors analysis. It should be noted that

test runs on the 2B plate used both types of gas, at times within the same test group. Discharge coefficient values are very consistent in

this respect, showing no change with change in gas type.

Beta Ratio 0.5 - FE-9/0-3B

Five days of testing were performed on this orifice meter. As with the

2B plate the gas type was changed during the first test run groups

taken. Discharge coefficient values observed at Reynolds numbers above

approximately 1,500,000 show little dependence on Reynolds number and

have a variation of 1 to 2 parts in 600 across the flow rate range above

15 inches of water. The observations taken at approximately 11 and 15

inches of water consistently fall below those taken at higher differential pressures , although the level of variation is within the propagation of error limits.

Beta Ratio 0.66 - FE-9/0-5B

The dependence of discharge coefficient values on Reynolds number is

small. Replication of the observations was not done and the character

of the results is similar to the 4A and 4B plates in that a small shift

is evident between values obtained on the two gas types. Again the

variation is within the limits given by the progation of errors analysis

.

Beta Ratio 0.75 - FE-9/0-6A and 6B

Discharge coefficient values decrease somewhat with Reynolds number for

both plates. Agreement of the results between the plates is well within

the propagation of errors limits as is the within and between group

variation. Changes in gas type show no effects.

205
4. Discussion of Test Results - FE-OABC

Tests on the FE-OABC meter tube were performed in 1984 only. The meter

tube had been refurbished, resulting in a very smooth meter tube. Tests were performed on 12 orifice plates.

Beta Ratio 0.2 - FE-9/0-1A and IB

Three flow rate settings only were run on the lA plate and only one on

the IB plate. The low Reynolds number points agree within the propagation of errors limits.

Beta Ratio 0.375 - FE-9/0-2A and 2B

Observations were taken at five flow rate settings for both plates. The

results are consistent between plates and test groups and within

propagation of errors limits. Results for both plates indicate a dependence of discharge coefficient on increasing Reynolds number

opposite to that predicted by the Stolz and Buckingham correlations.

Beta Ratio 0.5 - FE-9/0-3A and 3B

The results for both plates show a somewhat random pattern of variation

which is within the propagation of errors limits. The results for both

plates are consistent between themselves and within test groups.

Beta Ratio 0.57 - FE-9/0-4A and 4B

Observations were taken over the full flow rate range, and these agree

between the two plates and show a good level of consistency within and

between test groups.

Beta Ratio 0.66 - FE-9/0-5A and 5B

Observations were replicated on each plate over the full flow rate

range. For both plates the two highest Reynolds number points decrease

somewhat relative to the rest of the values . The magnitude of this

decrease is less than the propagation of errors limits, but appears to

be consistent across the two plates, although observations were taken on

the same day for both plates at the high Reynolds number points.

Beta Ratio 0.75 - FE-9/0-6A and 6B

Observations were taken across the full flow rate range, but were not

replicated. A decreasing dependence of discharge coefficient with

Reynolds number is observed. Consistency in the results between plates

is good.

ComTjarison of Results for FE-9ABC and FE-OABC

The results obtained for orifice plates tested in both meter tubes show

similar results for all plates having a sufficient niomber of test runs performed to make a reasonable comparison. This represents a comparison

between the two years of the work with the corresponding changes in the

206
measurement system and procedures made over the course of the project,

and suggests that the measurement systems have performed as expected and

do not appear to have contributed anomalies to the results.

VIII . Archiving of the Database

The extent of the complete database generated during the course of this

work is quite large. It is stored in computer readable form only and

available from either API or NBS . The bulk of the database consists of

the differential and static pressure transducer and platinum resistance

thermometer observations recorded for each test run, 150 sets of

observations. Each observation set contained an observation for each of

the thirteen pressure transduction devices and a forward and reverse current resistance value for each of the five thermometers.

The final database contains the normal operational malfunctions and

blunders encountered in obtaining any experimental database. These were

listed in the inventory given in section VII. The format used in

archiving the complete database in computer readable form is described

in Appendix G of this report. In archiving the database all of the

complete test runs recorded on magnetic diskettes by the data acquisition system are included, i.e., those marked for deletion and those not.

Test runs marked for deletion were excluded from the analysis. Test

runs interrupted before completion were never recorded by the data

acquisition microprocessor. Therefore, these cannot be archived.

207
IX. Acknowledgments

Many people have contributed their assistance to this project in one way

or another. The authors would like to express their gratitude to those

who have done so. Specific persons have worked closely with the authors

on various aspects of the project: NBS staff, NGPL staff and various

individuals associated with the API through its Committee on Petroleum

Measurement

In particular the principal investigator wishes to thank Nancy Skinner,

Carol Kimmel, and Monica Mock for their excellent work in preparing

intermediate manuscripts and Shirley Losh for completing the final

manuscript. Additionally, Dr. R. F. Kayser provided considerable

assistance in the editing of the final drafts of this document.

The efforts of various people at NGPL were essential to the completion

of this project as a joint one between NGPL and NBS. The authors would

like to thank Mr. Gary G. Less for his efforts in working with the

authors to achieve a successful conclusion to the project. Various of

the staff of the NGPL Station 113, Joliet, IL, contributed time and

insight to the startup and operation of the tests during both years of

testing. Messrs. J. Jones and G. Buchler provided timely information

and expertise during various phases of the project, particularly at

those times when diagnostic testing was required. The authors would

like to acknowledge the assistance of the two operators of the test

loop, Mr. Bud McDaniel in 1984, and Mr. Bob Libershire in 1985. We

would particularly like to acknowledge the excellent contribution of Mr.

McDaniel, deceased, who operated the test loop in 1984 and assisted with

operations in 1985. Mr. McDaniel 's constant attention to properly

performing the details of the project's operations produced a database

with a minimal amount of operator- induced error. Mr. McDaniel 's extensive experience in the operation of natural gas pipelines was of

much help in completing this project.

The contribution of Drs . K. Starling and J. Savidge of the University of

Oklahoma to the analysis portions of the project are gratefully acknowledged for the very timely access provided to the formulations of the

equation of state for natural gas mixtures and the associated computer

codes. This allowed the computation of results given here to reflect

the state-of-the-art in the area of natural gas physical property

calculations which have materially improved the quality of the final

results of the project. The numerous discussions with Dr. Savidge

during code development and debugging were essential to the final

completion of this aspect of the work.

Mr. J. Hord, Dr. M. M. Hessel, Dr. J. J. Ulbrecht, and Dr. J. W. Lyons

were instrumental in various phases of the project's management and

coordination with the API. The principal investigator would like to

thank Dr. H. G. Semerj ian for his encouragement and many suggestions

during the latter phases of the work.

Several individuals outside NBS contributed their time, effort and

thought. The membership of the API Orifice Database Steering Committee

(OSC) with little exception remained the same throughout the project,

208
and contributed suggestions, observations, and opinions to the work.

The members of the OSC maintained a high level of Interest throughout

the project and were instrumental in the control of its direction and

progress. In particular, Mr. W. A. Fling, as the API Project Manager,

maintained close contact with the work in its entirety, closely scrutinized the test run results as they were developed, and was instrumental

in identifying malfunctions in the system. Consequently, he and Mr.

Less consulted with the NBS principal investigator frequently, and both

were instrumental in the solution of several difficulties. The principal investigator would like to acknowledge the efforts of Mr. E. L.

Upp and Mr. J. Jones who worked closely with him in identifying difficulties with the differential pressure instrumentation in August 1984.

Also, the cooperative spirit and efforts of Mr. C. Britton and Mr. S.

Caldwell of CEESI in performing the final diagnostic tests done in

October 1985 are much appreciated.

209
X. References

[1] Whetstone, J. R. ; Cleveland, W. G, ; Baximgarten , G. P.; Woo, S.;

Croarkin, M. C. Measurements of coefficients of discharge for

concentric flange-tapped square-edged orifice meters In water over

the Reynolds number range 600 to 2,700,000, NIST Tech. Note 1264;

1989 June.

[2] Starling, K. E. ; Kumar, K. H. Computer program for natural gas

supercompresslblllty factor, custody transfer calculations and

process calculations using the OU/GRI correlation. 64th Annual GPA

Convention, Houston, TX, 1985 March; see also

Starling, K. E. ; Savidge, J. L. ; Kumar, K. H. PVT data base

evaluation methodology for highly accurate equation of state

development. Fluid Phase Equilibria; 1986 January; see also

American Gas Association Report No. 8, Amer. Gas Assoc, Arlington,

Va.

[3] Ely, J. F. ; Hanley, H. J. M. Prediction of transport properties. I. Viscosity of fluids and mixtures. Ind. Eng. Chem. Fund. 20(4):

323-332; 1981.

[4] Beitler, S. R. The flow of water through orifices. The Ohio State

University, The Engineering Experiment Station Bull. 89: 73; 1935

May.

[5] American Gas Association Report No. 3., Amer. Gas Assoc, Catalog

No. XQ0178, Arlington, Va. ; also American National Standard

Institute/American Petroleum Institute 2530.

[6] Stolz, J. A universal equation for the calculation of discharge

coefficients of orifice plates. ISO 5167, FLOMEKO 1978, IMEKO

Conference on Flow Measurement of Fluids, Groningen, North-Holland,

Amsterdam, 1978.

[7] Private Comm.unication, Starling, K. E. to Less, G. G.

[8] Sindt, C. Calibration of sonic Venturis. NBS Interim Report to Gas

Research Institute, Contract No. 5081-353-0042, 1984 September 11; see also

Fling, W. A. Private communication from CEESI concerning the

replacement of the 0.125-inch diameter nozzle's calibration.

Communication reproduced as Appendix F, this report.

[9] Johnson, R. C. Real-gas effects in critical -flow- through nozzles

and tabulated thermodynamic properties. NASA Tech. Note D-2565; see also

Johnson, R. C. Calculations of real-gas effects in flow through

critical-flow nozzles. Trans. ASME; J. Basic Eng.: 519-526; 1964

September.

210
[10] Jones, F. E. The air density equation and the transfer of the mass

unit. J. Res. Natl. Bur. Stand. (U.S.) 83(5): 419-428; 1978.

[11] Hilsenrath, J., et. al. Tables of thermodjmamic and transport

properties. New York: Pergamon Press; 1960. (Formerly Natl. Bur.

Stand. (U.S.) Circular 564.)

[12] Certain commercial equipment and instruments are identified in this

paper in order to describe the experimental procedures and results

adequately. In no case does such identification imply

recommendation or endorsement by the NIST (formerly National Bureau

of Standards) , nor does it imply the material or equipment is

necessarily the best available for the purpose.

[13] Sindt, C. F. ; LaBrecque, J. F. An accuracy statement for a facility

used to calibrate static pressure transducers and differential

pressure transducers at high base pressures. Natl. Bur. Stand.

(U.S.) Tech. Note 1052; 1982.

[14] U. S. Coast and Geodetic Survey.

[15] Touloukian, Y. S.; Kirby, R. K. ; Taylor, R. E.; Desai, P. D. Thermal expansion, metallic elements and alloys. Thermophysical

Prop, of Matter 12.

[16] Mann, D. B.; Brennan, J. A.; Sindt, C. F.; LaBreque, J. F.

;

McManus , S. E.; Kneebone , C. H. Gas orifice meter discharge

coefficients and determined by mass flow measurements. Natl. Bur.

Stand. (U.S.) NBSIR 83-1685; 1983 August.

[17] Sprenkle, R. E.; Courtright, N. S. Straightening vanes for flow

measurement. Mechanical Engineering 80: 71-73; 1958 February.

[18] Less, G. G., Private Communication.

[19] McCarty, R. D., Private Communication.

[20] Private Communication to B. R. Bateman from B. Gammon, Texas A & M

University, College Station, Texas.

[21] Ellington, R. T.; Starling, K. E.; Hill, M. J.; Savidge, J. L. Continued experimental and analytical services in support of the

api natural gas flow test program. Amer. Pet. Inst. , Washington,

D.C.

[22] Miller, R. W. Flow measurement engineering handbook. McGraw-Hill,

New York; 1983.

211

APPENDIX A

Descriptions of the API Natural Gas Test Facility

submitted by the

Natural Gas Pipeline Company of America

to

the American Petroleum Institute

Two reports were submitted to the American Petroleum Institute by the

Natural Gas Pipeline Company of America describing the natural gas test

facility. These are reproduced here in keeping with the intent of NBS

and API to document this orifice test program as completely as practicable. Two reports were made describing various aspects of the

test facility. No alterations have been made to either report with the

exception of placing page numbers on each page to be consistent with the

page numbering system of this document.

213
IMrX. NMlUKALi VjAd ICiOl TAV^XLiXXX

NATURAL GAS PIPELINE COMPANY OF AMERICA

JOLIET, ILLINOIS

Brief History of Joliet Test Facility

On pipeline systems with high flow rates and high pressures, there has

always been the concern of an accurate method of calibration of gas

measurement devices under these conditions. In recent years, there has been

considerable work on the use of critical flow nozzles as a secondary flow

standard for gas meter calibration. The sonic venturi nozzle, as you may be

aware, is a development of test work in the aerodynamic industry. Natural Gas

Pipeline Company of America has been instrumental in the application of the

sonic venturi nozzles as a high pressure calibration standard for turbine and

diaphragm meters under operating conditions.

The test site at Joliet, Illinois is set up to meet a variety of needs

associated with gas measurements. These included questions about the accuracy

of orifice coefficients at high pressure as well as increasing concerns about

the calibration of newer flow measuring devices as they come on the market.

Of major concern was whether meter manufactures published calibrations of

their devices were valid under actual field conditions. The sonic venturi

nozzle has proven to be a suitable device to answer these concerns.

214
When API originated the project to verify or update orifice coefficients,

one of their major concerns was verification of the extrapolated orifice

equation in the high Reynolds number range. The sonic venturi nozzle approach

seemed to be the only secondary standard capable of this possible

verification. Natural Gas Pipeline Company of America was chosen by API as

the contractor to run the high Reynolds number tests with sonic venturi

nozzles for the natural gas phase of the orifice coefficient project at the

Joliet, Illinois test facility.

Once the API/NGPLA contract was finalized, NGPLA proceeded to revise the

test loop to API specifications in February, 1984.

General Description of Test Facility

The API natural gas test facility for running high Reynolds number tests

on 6-inch and 10-inch diameter meter runs against sonic venturi nozzles as a

secondary standard is located at Natural Gas Pipeline Company of America's

regulator setting near Joliet, Illinois.

The test facility is installed in parallel with NGPLA' s mainline

regulators and is capable of flow rates in excess of 6,000,000 SCF/hr as

presently designed. The pressure cut across the station regulators is

sxifficient to assure sonic velocities in the application of sonic venturi

nozzles. The facility is free of compressor pulsation effects as the nearest

reciprocating compressors are approximately 100 miles from the test site.

215
The test facility is capable of using natural gas from two pipeline

systems, each of which has a different gas composition. The typical gas

composition of each source is referenced in table number one. All tests run

in 1984 were run only from the Gulf Coast source. This was preferable because

of the higher total methane and lower nitrogen content. In the 1985 tests,

this was not possible and either source of gas was utilized as operating

pressures and availability dictated.

REPRESENTATIV]3 ANALYSIS

Gulf Coast Amarillo

Gas Gas

Mol % Mol %

.30 4.97

96.30 88.75

.60 .46

1.65 3.97

.40 1.20

.10 .13

.10 .27

.05 .07

.03 .07

.07 .10

Nitrogen

Methane

Carbon Dioxide

Ethane

Propane

2-Butane

n-Butane

2-Pentane

n-Pentane

Hexanes Plus

Table 1

Modification of the test facility to API specifications was completed in

late June for the 1984 series of tests.

1984 System and Piping Configuration

Figure #1 is a general schematic of the 1984 test loop configuration.

216
Reference Point (1) Figure I

A one million Btu/hr water bath mainline heat exchanger is installed to

increase the flowing gas to a temperature above the hydrocarbon dew point

to prevent the possible formation of hydrocarbons in the sonic venturi

nozzle throat. Gas pressures to the nozzle inlet may vary between 550

psig to 720 psig and nozzle outlet pressures may vary from 385 psig to 415

psig from day to day dependent on NGPLA's load conditions. Flowing gas

temperatures are dependent on the capacity of the heat exchanger at a

particular flow rate. At low flow rates, a flowing gas temperature of

92°F may be attained, while at the largest flow rates, the maximum

flowing gas temperature may be 60°F.

An 89 foot long section of straight pipe precedes the orifice meter test

section.

Reference Point (2) Figure I

A 6 X 10 X 6 inch Sprenkle flow conditioner was installed for the 6-inch

meter run tests and a 10 X 16 X 10 inch Sprenkle was installed for the

10-inch meter run tests.

Reference Point (3) Figure I

The 6-inch and 10-inch diameter API test meter runs were installed in this

location for each of their test periods.

217
Reference Points (4) (5) (6) Figure I

The secondary section is a four nozzle manifold system. A combination of

eleven critical flow venturi nozzles were used ranging in size from 0.094

inches to 2.338 inches, reference table number 2. The five smallest

nozzles fit into two inch diameter pipe holders. The six and ten inch

holders were removable and could be replaced with any combination of the

four 2-inch holders.

Sonic Venturi

Nozzle Throat

Diameter-Inches

Nozzle Holder

Size - Inches

0.095

0.1259

0.1879

0.2491

0.3742

0.5328

0.7537

0.064

1.375

1.945

2.330

2

2

2

2

2

6

6

6

6

10

10

Table #2

218
Tube bundle type straightening vanes were installed ahead of each sonic

nozzle, reference point (4) Figure I

Block and bleed valves installed in each nozzle run assure a positive shut

off when a nozzle was taken out of service, reference point (6) Figure I.

Individual flowing gas temperatures were measured upstream of each nozzle

with electronic thermo sensors. Orifice meter tube flowing gas

temperatures were measured with electronic thermo sensors at the outlet of

the downstream spool of the API t\ibe.

Individual static pressures were taken upstream of each sonic nozzle with

individual electronic static pressure transducers. Static pressures were

taken downstream of each nozzle to assure that sonic flow conditions were

present for each data point. The upstream differential pressure tap of

both the 6 and 10 inch meter runs was used for the orifice meter static

pressure.

Differential pressures across the orifice plate were determined with two

0-30 inch range and two 0-200 inch range Rosemount Model 1151 differential

pressure transducers. The two 0-200 inch range transducers were later

replaced with two 0-150 inch range transducers with improved resolution

resulting.

All electronic transducers were calibrated every morning against standards

that had been calibrated or verified by the National Bureau of Standards.

219
A Ruska Differential Pressure Gauge Model DDR 6000 with a 0-200 inch

differential range was utilized as a standard for calibration of the

differential pressure transducers.

The static pressure transducers were calibrated against an AMETEK Model

HK-1000 Pressure Tester as a standard.

The ENCAL chromatograph was calibrated daily against a standard gas sample

prepared by the National Bureau of Standards.

Reference Point (10) Figure I.

A gas sampling probe is installed at this point to supply a continuous on

line sample of the flowing gas for the ENCAL gas chromatograph. The

sample gas is preheated with a catalytic heater before the pressure is cut

to 20 psig at the probe location. The sample line from this point to the

ENCAL gas chromatograph is insulated and heat traced it's entire length.

A continuous bleed is provided at the chromatograph end to increase the

gas velocity in the sample line.

The critical fldw venturi nozzles are of the circular arc inlet with no

cylindrical throat section. All of the nozzles listed in table number 2

were calibrated at the Colorado Engineering Experiment Station, Inc.

(CEESI) Nunn, Colorado under the sponsorship of the Gas Research Institute

and with the direct supervision of the National Bureau of Standards.

220
Reference Points (7) (8) (9) Figure I.

A 12' K 25' instrument building is adjacent to the test facility. One 12

X 12 room for the electronic transducers is equipped for Class II,

Division I service. The 12 X 12 room houses the computer, an ENCAL gas

chromatograph and the high pressure differential tester. Both rooms are

air conditioned.

The entire length of the test loop including approach piping and the

nozzle manifold is insulated with one inch thick plastic coated foam

rubber type of insulation to reduce ambient temperature changes during

each test run.

A review of the 1984 data indicated that a repeat of the gas phase of

testing should be done in an attempt to improve data scatter at low

Reynolds number on the lower beta ratio plates. Figure II is a general

schematic of the 1985 test loop configuration. The following

modifications were made on the test facility in an attempt to improve the

system:

Reference Point (4X) (5X) (6X) (IIX) Figure II

A four nozzle manifold of 2-inch holders for the smaller nozzles was

fabricated and installed in parallel with the larger four nozzle manifold

system. A removable blind plate was installed at point (IIX) to isolate

the small nozzle manifold from the large nozzle manifold when no nozzles

in the large manifold were in service.

221
The 1984 computer program utilizing a maximum of four static pressure

transducers for four sonic nozzles at one time was not changed. For this

reason, of the eight nozzles available, flow rates were limited to any

combination of nozzles up to a maximum of four nozzles at one time. Since

there were only four static pressure transducers available for the eight

nozzles, the static pressure sensing lines were manifolded to sense the

static pressure of the sonic nozzle in service. For example, static

pressure sensing line from the #1 run of small nozzle manifold system was

manifolded to the static pressure sensing line from the #1 nin of the

large nozzle manifold system etc. The same system was also utilized for

the temperature sensors by physically connecting the temperature sensor

for the nozzle in service to the junction box terminal. Temperature

sensors and pressure taps not in service were either disconnected or

valved off.

The two 0-150 inch and two 0-30 inch Rosemount pressure transducers were

replaced with two 0-200 inch and 0-40 inch Honeywell differential pressure

transducers. The new transducer units were internally programmed to

compensate for static pressure and ambient temperature effects.

222
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API NATURAL GAS TEST FACILITY

NATURAL GAS PIPELINE COKPANY OF AMERICA - JOLIET, ILLINOIS

SYSTEM AND PIPING CONFIGURATION DESCRIPTION

1984 and 1985 COMBINED REPORT

General Description

The API natural gas test facility for running high Reynolds number tests

on 6-inch and IC-inch diameter meter runs against sonic venturi nozzles as a

secondary standard is located at Natural Gas Pipeline Company of America's

regulator setting near Joliet, Illinois.

The test facility is installed in parallel with HGPL ' s mainline regulators

and is capable of flow rates in excess of 6,000,000 SCF/hr as presently

designed. The pressure cut across the station regulators is sufficient to

assure sonic velocities in the application of sonic venturi nozzles. The

facility is free of compressor pulsation effects as the nearest reciprocating

compressors are approximately 100 miles from the test site.

The test facility is capable of using natural gas from two pipeline

systems, each of which has a different gas composition. The typical gas

composition of each source is referenced in table number one. All tests run

in 1984 at this location were run only from the Gulf Coast source because of

its higher total methane and lower nitrogen content. In the 1985 tests,

either source of gas was utilized as operating pressures and availability

dictated.

The system and piping configuration of the test facility for both the 1984

and 1985 testing periods were basically the same except for the differences as

noted in the appendix.

225
1984 System and Piping Confipurati'on

1. Reference Figure I item 1 & Photo 1.

A one million Btu/hr water bath mainline heat exchanger is installed to

increase the flowing gas to a temperature above the hydrocarbon dew point

to prevent the possible formation of hydrocarbons in the sonic venturi

nozzle throat. Gas pressures to the nozzle inlet may vary between 550

psig to 720 psig and nozzle outlet pressures may vary from 385 psig to 415

psig from day to day dependent on NGPL ' s load conditions. Flowing gas

temperatures are dependent on the capacity of the heat exchanger at a

particular flow rate. At low flow rates, flowing gas temperatures of

92°F may be attained, while at the largest flow rates, the flowing gas

temperature may be 60°F.

2. An 89 foot long section of straight pipe precedes the orifice meter test

section.

3. Reference Figure 1 item 2 S< Figure 8.

A 6 X 10 X 6 inch Sprinkle flow conditioner was installed for the 6-inch

meter run tests and a 10 X 16 X 10 inch Sprinkle was installed for the

10-inch meter run tests.

4. Reference Figure 1 item 3 and Figures 11 and 12 for installation and

dimension details of the 6-inch and 10-inch diameter API test meter runs.

5. Reference Figures 1 thru 7 & Photos 1, 7, 8, 9, 10.

The secondary standard section is a four nozzle manifold system. A

combination of eleven critical flow venturi nozzles were used ranging in

size from 0.094 inches to 2.338 inches, reference table number 2. The

five smallest nozzles fit into two inch pipe holders. The six largest

nozzles fit into the six and ten inch diameter holders. The six and ten

inch holders may be removed and replaced with any combination of four

2-inch holders illustrated in Figure 7 to accommodate the smaller nozzles.

226
Block and bleed valves installed in each nozzle run assure a positive shut

off when a nozzle is taken out of service.

6. Reference Figures 2, 7 & Photo 9.

Individual flowing gas temperatures are measured at points "A" for the

6-inch meter run, point "B" for the 10-inch meter run, points "C, D, E and

F" for the 6 and IC inch nozzle holders and point "G" for each of the four

2-inch nozzle holders illustrated in Figure 7.

7. Reference Figures 2 and 7.

Individual static pressures are taken at points "H, I, J and K" for the 6

and 10 inch nozzle holders and at point "R" for each of the four 2-inch

nozzle holders for the upstream nozzle pressure, and at points "L, M, N

and P" for the downstream nozzle pressures. The upstream differential

pressure tap of both the 6 and 10 inch meter runs is used for the orifice

meter static pressure.

8. Reference Figure 1 item 10 & Photo 5:

A gas sampling probe is installed at this point to supply a continuous on

line sample of the flowing gas for the gas chromatograph. The sample gas

is preheated with a catalytic heater before the pressure is cut to 20 psig

at the probe location. The sample line from this point to the

chromatograph is insulated and heat traced it's entire length. A

continuous bleed is provided at the chromatograph end to increase the gas

velocity in the sample line.

9. Reference Figure 1 item 5, Figures 9, 10 & Photo 6.

The critical flow venturi nozzles are of the circular arc inlet with no

cylindrical throat section. All of the nozzles listed in table number 2

were calibrated at the Colorado Engineering Experiment Station, Inc.

(CEESI) Nunn, Colorado under the sponsorship of the Gas Research Institute

and with the direct supervision of the National Bureau of Standards.

227
10. Reference Figure 1 items 7, 8, 9 Figure 13 & Photos 2, 10.

A 12' X 25' instrument building is adjacent to the test facility. One 12

X 12 room for the electronic transducers is equipped for Class II,

Division I service. The other 12X12 room houses the computer, gas

chromatograph and the high pressure differential tester. Both rooms are

air conditioned.

.

11. Reference Photos 4, 8, 9.

The entire length of the test loop including approach piping and the

nozzle manifold is insulated with one inch thick rubber foam plastic

coated type of insulation to eliminate ambient temperature changes during

each test run.

REPRESENTATIVE ANALYSIS

Nitrogen

Methane

Carbon Dioxide

Ethane

Propane

2-Butane

n-Butane

2-Pentane

n-Pentane

Hexanes Plus

Sonic Venturi

Nozzle Throat

Diameter- Inches

urms

0.1259

0.1879

0.2491

0.3742

0.5328

0.7537

0.064

1.375

1.945

2.330

bult Coast Amari 1 lo

Gas Gas

Mo^ % Mol %

.30 4.97

96.30 88.75

.60 .46

1.65 3.97

.40 1.20

.10 .13

.10 .27

.05 .07

.03 .07

.07 .10

Table 1

Nozz"le Holder

Size - Inches

Z2

2

2

2

6

6

6

6

10

10

Table #2 228
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NOTES ( ^AB,l^lCATOl^;

I. ALL WELPS TO BE FULLY IKJ5P&CTEP "RAPIoqRAPHlCALLY

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4. ALL TAPS IM TEST LOOP SHALL . BE PJ^ILLEP T^iS.U. AT

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Photo No. 1 (1984-85 Configuration)

Inlet line heater to preheat flowing gas stream above any danger

of hydrocarbon liquid dropout in the sonic nozzle throat

Photo No. 2 (1985 Pip'ing Configuration)

Two room instrument building with six inch API meter run in

foreground. The four nozzle manifold is behind the building

242
Photo No. 3 (1984-85 Configuration)

Six inch orifice flange

Photo No

Six inch orifice flange with

insulation jacket. Entire

exposed test loop piping

is insulated to reduce

ambient temperature affect,

especially when a cloud passes

over.

243
Photo No. 5 (1984-85 Configuration)

Sample probe house with catalytic

heater to preheat gas sample for

analysis by chromatograph.

244

Photo No. 6 (1984-85 Configuration)

Typical sonic venturi nozzle of Smith-Matz design,
Photo No. 7 (1984-85 Configuration)

View of four block and bleed Orbit valves for large

nozzle manifold system.

Photo No. 8 (198A Configuration)

View of four sonix nozzles manifold with two 2-inch nozzle

holders and two 6-inch nozzle holders installed.

245
Photo No. 9 (1984 Configuration)

2-inch nozzle holder installed in large manifold system.

Photo No. 10 (1984 Piping Configuration)

Sonic nozzle manifold and instrument building, note air

conditioners. Air conditioner on right is explosion proof

for hazardous area. The building remained the same for both

1984 and 1985.

246
Photo No. 11 (1984-85 Configuration)

Two 0-150 inch differential pressure

transducer at top, 400-700 psig static

pressure transducer in center, and 0-30

inch transducers on bottom all for the

orifice meter. The 0-150 inch and 0-30

inch differential pressure transducers

were replaced with 0-200 inch and 0-40

inch transducers for ambient temperature

and static pressure effect.

Photo No. 12 (1984-85 Configuration)

Entire transducer board, four static pressure transducers

on bottom left are for measuring upstream static pressure

for each sonic nozzle. Four static pressure transducers top

left measure pressure downstream of each sonic nozzle.

247
Photo No. 13 (1984-85 Configuration)

Chromatograph standard sample cylinder

installed in separate insulated heated

enclosure to ensure that no condensation

of compoi^ents occurs.

Photo No. 14 (1984-85 Configuration)

Ametek static pressure dead weight tester vith nitrogen

bottles to daily calibrate all static pressure transducers.

248
/ Photo No. 15 (1984-85 Configuration)

Test loop computer, data is collected

from four runs for each flow rate with

150 data points per five minute run.

Photo No. 16 (1984-85 Configuration)

Gas chromatograph a complete gas

analysis is made every 13 minutes.

Bottom left side is the Ruska

DDR 6000 instrument for daily

calibration of all the differential

pressure transducers.

249
APPENDIX I

ILLUSTRATIONS AND PHOTOS

OF 1985

PIPING AND INSTRUMENTATION REVISIONS

250
Prelim'nary review of the 1984 data indicated that a repeat of the gas

phase of testing should be done in an attempt to improve the data scatter at

low Reynolds number on the lower beta ratio plates. The following

modifications to the system were made in order to eliminate or improve certain

problem areas:

1. Reference Figure 1-A, 2-A, 7-A, & Photos 17, 18, 19, 20, 21, 22.

A four nozzle manifold of 2-inch holders for the smaller nozzles was

fabricated and installed in parallel with the larger four nozzle manifold

system.

The 1984 computer program utilizing a maximum of four static pressure

transducers for four sonic nozzles at one time was not changed. For this

reason, of the eight nozzles available, flow rates were limited to any

combination of nozzles up to a maximum of four nozzles at one time. Since

there were only four static pressure transducers available for the eight

nozzles, the static pressure sensing lines were manifolded as illustrated

in photo number 22. For example, static pressure sensing line from the #1

run of small nozzle manifold system was manifolded to the static pressure

sensing line from the #1 run of the large nozzle manifold system etc. The

same system was also utilized for the temperature sensors by physically

connecting the temperature sensor for the nozzle in service to the

junction box terminal. Temperature sensors not in service were

disconnected. Reference photo number 24.

2. Reference Photo 23.

The two 0-150 inch and two 0-30 inch differential pressure transducers

were replaced with two 0-200 inch and two 0-40 inch differential pressure

transducers. The new units were internally programmed to compensate for

static pressure and ambient temperature effects.

3. All thermo-well type temperature sensors were replaced with direct

insertion sensors on October 3, 1985.

251
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254
Photo No. 17 (1985 Configuration)

View of eight nozzle manifold system

Photo No. 18 (1985 Configuration)

View of four 2-inch nozzle holders. 2-inch block, and bleed

valves are upstream of nozzles.

255
Photo No. 19 (1985 Configuration)

View of 10-inch insulated API meter run and 2-inch nozzle holders

Photo No. 20 (1985 Configuration)

Close up view of 2-inch nozzle holders 256
Photo No. 21 (1985 Configuration)

View of 10X10X14" Tee branching off to the 4-inch header for 2-inch

nozzle holders. Temperature sensor for the meter run in inserted in

the top of Tee. A 10-inch blind is installed between the downstream

Tee flanges to isolate the large nozzle holder system from the small

nozzles at low flow rates.

Photo No. 22 (1985 Configuration)

Static pressure sensing line manifold to assure isolation of

large nozzle system static pressure from small nozzle system

static pressure. 257
Photo No. 23

(1985 Configuration)

Two 0-200 inch pressure and

temperature compensated differentia

pressure transducers at top,

400-700 psig static pressure

transducer in center , and two

0-40 inch pressure and temperature

compensated differential pressure

transducers on bottom, all for

orifice meter.

#

Photo No. 24 (1985 Configuration)

Temperature sensor junction box 25f
APPENDIX B

Operational History of the Project

Introduction

This appendix gives a detailed chronological account of the major events

which occurred during this project. It is written to provide a record

of the progress and significant events which occurred during the project. Significant portions of this appendix were taken from the monthly

progress reports prepared for the API by the NBS Principal Investigator

(J. Whetstone). These have been edited primarily for clarity in the

context of this document and for proper language usage. Verbatim

excerpts are usually indented for the sake of clarity. As was mentioned

in the introduction of this report, this project was one of three

conducted simultaneously by the API between 1982 and 1987. This project

was somewhat unique among the three in that responsibility for various

portions of the project was split between the National Bureau of

Standards (NBS) and the Natural Gas Pipeline Company of America (NGPLA)

.

NBS provided the measurement systems and associated instrumentation and

performed the analysis of the data given previously in this report.

NGPLA provided the use of its test site located at its Joliet, Illinois

Station and was responsible for operation of the tests.

From the outset a strong advisory role was played by the API Program

manager and the API's Orifice Meter Database Steering Committee (OSC)

which was composed of the following persons:

R. E. Beaty - Committee Chairman,

AMOCO Production Co.

! D. W. Kemp - Cities Service Co.

Occidental Petroleum Corp.

# W. A. Fling - Cities Service Co.

Occidental Petroleum Corp. * E. L. Upp - Daniel Industries

R. G. Teyssandier - Daniel Industries

H. L. Bean - El Paso Natural Gas. Co., Retired

T. L. Hilburn - Phillips Petroleiam

G. G. Less - NGPLA

R. L. Schreibeis - API Staff representation

J. K. Walters - API Staff representation

! D. W. Kemp - ex officio membership on the committee as Chairman,

API, Committee on Petroleum Measurement

# API Program Manager

* R. Teyssandier replaced E. L. Upp at approximately the mid-point

of the work.

259
The membership of this committee stayed essentially the same throughout

the course of the project. Frequent meetings of this committee occurred

and, at times, strongly influenced the course of the planning and exec- ution of the project's technical direction. No major change in the work

was made without consultation and agreement of the committee

.

The Initial plans for the project called for a single testing period to occur during the summer and early fall of 1984. However, events occurring in the intermediate Reynolds number project influenced the high

Reynolds number project and a second season of tests were completed in

1985. These tests were run only during warm weather at the test site to

minimize or eliminate the possibility of condensation of some of the

heavier hydrocarbon fractions in the natural gas

.

II. Development and Conmissioning of Measurement Systems

Initial planning discussions concerning the type of instrumentation and

standards to be used in the measurement systems were held in 1982 and

early 1983 in conjunction with reviews of the work then in progress on

the intermediate Reynolds number project [Bl]. The general philosophy

and approach taken in the intermediate Reynolds number project was followed in planning the measurement systems. Particularly, the use of

working standards which were closely tied to U. S. national standards

was emphasized. This was particularly true for the pressure measurements . Both absolute and differential pressure working standards were planned since the transducers used for these measurements were of industrial quality and it was not clear at the outset at what level of temporal stability these would perform. Additionally, laboratory grade

transducers having the required explosion-proof housings and construction were not readily available. Therefore, a double level of redundancy in the differential pressure transducers, and the capability to

calibrate both differential and absolute pressure transducers was planned for the instrumentation system. The specifications for the

various transducers (pressure and temperature), data logging, and data

acquisition and storage computer were completed in early 1983 and were

assembled and tested at the NBS-Boulder laboratories by early 1984.

These systems were installed at Joliet in late May of 1984 in preparation for testing to begin in June. During the course of the installation of the systems, the NGPLA personnel responsible for operation of

the test were trained in the operation of the data acquisition equipment

and familiarized with the various procedures required of the operator by

the data acquisition computer software.

260
III. 1984 Data Collection Season

The 1984 data collection season began in early July with test runs on

the FE-7ABC meter tube using both sets of orifice plates. A preliminary

review of the results of the tests taken in July and early August showed

inconsistent values for the high and low range differential pressure

transducer means and the discharge coefficients derived from them for

some, but not all of the test runs. Additionally, this inconsistency

was intermittent.

A. Investigation of Intermittently Inconsistent Differential Pressure

Measurements

An investigation of possible causes for this situation was made by NGPLA

operating staff, the NBS principal investigator (J. Whetstone) and Mr.

Upp as representative of the OSC. This investigation was performed on August 21 through 23. Its results were given in a report to the full

OSC shortly thereafter. The following description is excerpted from

that report and has been edited for clarity.

August 21 - 3:00 to 9:30 PM

The pressure values obtained from the 20- inch and the 200- inch

differential pressure transducers in their range of overlap, i.e.,

30-40 inches of water, were not in good agreement. Using the

computer software (scan program) , the pressure values could be

observed. Tests of the the computer software were made. By the end

of the day it was clear that the software was operating properly.

Certain modifications to the transducer calibration program were made

to allow a 20-point calibration of each set of transducers. Also it was observed that the pressure lines connecting the RUSKA DDR-6000 to

the transducer manifold were not insulated and that in the transducer

room these were in the direct air stream from the air conditioner.

The air conditioner was turned off and the doors were opened.

Subsequent calibration operations proceeded more quickly because the

time necessary for the pressure to stabilize at each calibration

point was considerably reduced. This was particularly true in the

pressurizing stage of the procedure.

August 22

The differential pressure transducers were calibrated at 270 and at

600 psig. These two calibration passes agreed with one another

rather well. After completing the calibration procedures the scan program was entered, and the differential pressure values at zero differential pressure conditions were displayed on the console

screen. These values are updated on the screen every 10 seconds and

agreed within .05 Inches of water of each other. The transducers

were then cycled to atmospheric pressure and to 600 psi and to 271

psi. During these operations the transducers were exposed to large

pressure differentials. After one of these excursions the values of

the zero differential pressure values computed for the 200- inch

transducers differed from those of the 20- inch transducers by as much

as 0.5 inches of water. The values of the two 20- inch transducers

261
during these operations were always within 0.1 inch of water or less

of zero. The zero differential pressure values for the 200- inch

transducers were continually changing with each pressurization step.

The pressure was set to 600 psi and the calibration pump was used to

pressurize the transducer manifold to various levels up to approximately 200 inches of water differential. After each of these cycles

the zero differential pressure values for the 200- inch transducers

changed while the 20- inch transducers remained at their previous values, very near zero. During this entire operation the scan program

was running, using the coefficients obtained from the last 600-psi

calibration done between 2:30 and 3:30, i.e., nothing was done to the

computer or to its software

The scan program was left running over night. The values displayed

are given below for various times. DPI and DP2 are the 20-inch

transducers. The pressure units are inches of water.

DATE/TIME DPI DP2 DP3 DP4

8/22 5:45 -0.01 0.02 -0.13 -0.15

9:23 -0.04 0.02 0.30 0.36

8/23 7:28 -0.06 0.01 0.49 0.58

Augus t 2 3

The differential pressure transducer procedure was modified for a 20-point calibration to give a larger number of observation points to

check whether the quadratic calibration equation was causing a problem. This calibration was completed and the scan program was

entered. It used the coefficient values gotten from the 20 calibrations.

Time DPI DP2 DPS DP4

10:50 0.02 0.04 0.04 0.01

Put a differential of 100 inches on the transducers.

0.01 0.03 -0.04 -0.08

Repeat the pressure cycle

0.02 0.03 -0.03 -0.05

The pressurizing pump was used to set several differential pressure

values in the overlap zone of the transducers. The pump was then

valved off. The following were recorded from the scan program.

4.86 4.86 4.80 4.78

9.72 9.69 9.65 9.61

19.86 19.82 19.79 19.77

35.12 35.12 35.04 35.00

262
The transducer manifold was pressurized to 100 inches of water and a similar schedule was run.

36.79 36.82 36.77 36.74

30.90 30.89 30.86 30.84

5.75 5.74 5.70 5.66

(The following is a record of the section of the notebook recorded in

my absence by E.L. Upp.) Shut down to go to 100 inches then back to zero to check the method of bleed down. The pump is backed off

before the bypass is opened. The 200- inch goes to negative diff.

press, of 38 inches and zero shows a great shift, however if the

bypass is opened before the pump is backed off the zero's agree and

diff. press, agree to 35 inches on all four transducers. See data

below.

9.91 9.89 9.85 9.81

16.73 16.68 16.66 16.62

23.14 23.09 23.07 23.04

30.69 30.66 30.59 30.57

35.30 35.30 35.20 35.17

28.94 28.91 28.84 28.82

19.37 19.32 19.29 19.25

8.72 8.70 8.65 8.60

.02 .04 -0.03 -0.07

The transducer manifold was valved off the nitrogen bottle supply

used in calibration procedures and in the tests described above, and on to the orifice plate taps with no flow in the line. The line

pressure was approximately 700 psi. By manipulating the crossover

valves and changing to a pressure of 700 psi the zero differential

pressure values displayed on the screen were the following.

Time DPI DP2 DP3 DP4

0.00 0.04 0.35 0.33

The transducer manifold was valved back to the nitrogen bottle with

no change resulting in the zero differential pressure values.

During the operations described above the supposition was put forth

that the large shifts in the 200- inch zero values were caused by

allowing the transducers to experience large negative differential

pressures. To test this the following tests were performed and data

taken.

Time DPI DP2 DP3 DP4

12:00 0.01 0.04 0.36 0.32

Put a small negative differential pressure on the manifold and return

to crossed over condition.

263
0.01 0.04 0.35 0.32

Go to +50 inches diff. press, and return with at least a -1.5 in. of

water excursion shown on the screen during the operation.

0.01 0.04 0.35 0.32

Repeat but go to +200 in. diff. press. A larger negative swing was observed when returning.

0.01 0.04 0.28 0.23

Repeat to +150 in. water with a -36 in. displayed on the negative

swing

.

12:19 0.01 0.03 0.25 0.21

Go to Lunch with the same values as at 12:19 displayed at 1:50

Conclusions Drawn From These Data

The 200- inch transducers are affected by pressure excursions which

bring them against their mechanical stops. Especially influential

are negative excursions. The magnitude of the shifts in the response

of the 200- inch transducers can be as large as plus or minus 0.5

inches of water. The 20-inch transducers are much more stable,

especially DP2

.

Subsequent Actions and Recommendations

1. The 200-inch transducers should be replaced by 150-inch

transducers taken to Joliet by E. L. Upp the previous week.

2. E. L. Upp and W. A. Fling would assess the data to determine

which test points and orifice plates should be rerun.

3

.

A change in procedures and/or a modification in equipment should

be effected to minimize or eliminate negative excursions of the

differential pressure transducers.

After a discussion with Jim Jones, NGPLA Joliet Station Superintendent, Dr. Whetstone decided to reduce the number of test points taken

at each flow rate from six to four. This corresponds to two

13-minute cycles of the Encal chromatograph rather than three. The

reduction in the quantity of data at each flow rate setting should

not adversely affect the quality of the database while increasing the

number of plates which can be tested in a day.

Following discussions of the situation with the OSC, two 150- inch of

water transducers were installed the last week of August. During the

week of September 7, 1984 several transducer calibration passes were made with the result that one of the new 150 -inch transducers appeared

to be performing approximately 10 times worse than the other, i.e., one had a residual standard deviation for the fit of 0.001 psi while the

264
other had a residual standard deviation of approximately 0.014 psi.

Analysis of the calibration data and the fitting procedure showed that

the quadratic model used was not properly representing the response of

the second transducer. The model used to fit the calibration data was modified to a cubic. This change reduced the second transducer's

residual standard deviation value to a level equivalent to that of the

first. A cubic model was used for both of the transducers.

The calibration procedures were modified somewhat to reduce the

possibility of large differential pressure excursions by setting the

static pressure at which the procedures were performed to a value very

near the operating pressure of the pipeline.

Following these changes the testing program was resumed. The OSC had

decided to repeat all of the tests on the orifice plates run previously.

To clearly mark the break in the data collected, the test run nuimber

used to begin this block of tests was set at 501 which was the first

test performed on September 10, 1984. Subsequent test runs were numbered sequentially ending with test run 970 taken on November 11,

1984.

IV. The 1985 Data Collection Season

Events occurring in the companion Intermediate Reynolds Number Project

[Bl] during the winter and spring of 1985 relating to corrosion- induced,

surface -roughness effects on discharge coefficient measurements and a desire to repeat certain of the test runs taken the previous year caused

the OSC to decide to extend the project. Differential pressure transducers, which were thought to have better operating characteristics,

were available, and repetition of certain of the test runs performed in

the cooler part of the testing season could be re-tested at a time when

the pipeline gas was warmer.

Test Loop Modifications

Additionally, a second nozzle manifold was fabricated and installed to

substantially eliminate the need to depressurize the pipeline to change

nozzles. The second manifold allowed all but one of the nozzles to be

mounted in the test loop. This manifold was 2 -inches in diameter and

held four of the five small nozzles allowing a broader range of flows to

be achieved without physically changing nozzles with the attendant test

loop pressure cycling. A requirement of the instrumentation associated

with the new manifold was that it should be configured and operating

procedures modified such that no changes in the data acquisition, analysis and storage software was necessary. The two manifolds were fitted

with pressure tap line valves so that the transducers measuring the nozzle plenum pressures could be paired, thereby maintaining the use of

four pressure transducers. The pressure transducers on the downstream

side of the nozzles were not paired. Therefore, when the small nozzles

were in operation the downstream pressures were not measured, and the

recorded values were those of the larger nozzles which were not

operational and were generally at substantially lower pressures.

265
Thermometers were installed in the small nozzles. This increased the

set of thermometers in potential use to nine. Operating procedures were

changed so that the operators physically switched the various

thermometer leads to the four ports of the data logger. A pair of PRT's

were assigned to each data logger port in correspondence with the

pairing of the nozzle static pressure transducers.

The new differential pressure transducers and the nozzle manifold were installed and operational checks were completed July 23, 1985. Test run number 1 was taken July 24, 1985. Data collection activities ran smoothly with no major difficulties in operations. A new NGPLA operator

had been assigned to the project for the 1985 season which resulted in

the expected changes in some details of the operation, but no significant difficulties were identified in the operating procedures.

The initial meter tube tested in the 1985 testing season was the FE-9ABC

meter tube using 10 of the orifice plates of the A and B sets. These

tests were completed in early September. The second meter tube to be

tested was FE-7ABC which had been run the previous summer and fall. The

test run data was taken for most of the plates in early October. The

scatter in data taken in 1984 and 1985 indicated that a systematic

effect may be present. To investigate the possibility of malfunctions

in the instrumentation and computer systems , a group of tests was made

jointly by NBS and personnel from Colorado Engineering Experiment

Station, Inc. The following is the report of those diagnostic tests.

It has been edited for clarity here, but is given without essential

deletions. Editorial comments or adjustments are enclosed in brackets

{). To be specific concerning the equipment in use, manufacturer's

names and model numbers are given in this report. In doing so the

National Bureau of Standards in no way explicitly or implicitly

recommends or endorses any such devices or instruments [B2]

266
NBS/CEESI Diagnostic Test

Summary Report

of

Joliet Test Loop Instrumentation System Investigation

performed by

C. L. Britton - CEESI

S. H. Caldwell - CEESI

W. G. Cleveland - NBS

J. R. Whetstone - NBS

During October 14 through 18, 1985

submitted

October 25, 1985

This summary report describes tests of the instrumentation system

installed at the Natural Gas Pipe Line Company of America's Joliet, 111.

test loop as part of the API sponsored Orifice Database Project.

Colorado Engineering Experiment Station. Inc. (CEESI) and National

Bureau of Standards personnel performed these tests. The purpose of

this investigation was to determine whether the source of the scatter in

the data collected during 1985 at Joliet could be isolated, and, if so,

what measures could be implemented to reduce the variation in the data.

I. Auxiliary Equipment

Messrs. Britton and Caldwell brought several pieces of auxiliary equipment to be used to check the operation of the currently installed

instrumentation system. This included measurements of temperatures

other than those currently logged by the instrumentation system. The

auxiliary equipment used were the following.

1. Hewlett Packard Model 7090A Measurement Plotting System,

2. Fluke Model 2190A Digital Thermometer,

3. Fluke Model 2300A Scanner,

4. Fluke Model 8520A Digital Multimeter,

5. Mensor - 2500 psid Digital Pressure Transducers (2),

6. Ametek Model PK-300 Deadweight Tester, and

7. Honejrwell Differential Pressure Transducer Model

STD120-3000.

The Honeywell transducer was installed with approximately 2 feet of

stainless tubing between it and the pressure taps of the 6 -inch orifice

meter, FE-7ABC. It had been calibrated during the week of October 7,

1985 at CEESI. Due to the restraints of the piping system, CEESI 's Honeywell transducer was not calibrated after installation in the

system. (The hand Pump used to pressurize the differential pressure

transducer piping circuit for calibration was not large enough to handle

267
the added volume.) This transducer was connected in parallel with the

four Honeywell differential pressure transducers of the instrumentation

system.

One of the Mensor transducers monitored the downstream tap of the

orifice plate and was connected to the piping system at the Rosemount

static pressure transducer. The second Mensor transducer monitored the

inlet pressure of Nozzle Run D in the 2 -inch manifold and was connected

at the corresponding Rosemount transducer on the instrument panel.

The Fluke digital thermometer was installed with four thermocouple

probes. The locations of these probes were the following.

1In the water bath of the gas fired heater located upstream

of the orifice meter

2. On the outer surface of the orifice meter near the orifice

flange

3. Upstream of the orifice, in the gas stream. The penetration

into the gas stream was made approximately 50 feet from the

orifice meter flange.

4. Downstream of the orifice plate, in the gas stream, located

approximately six inches from the bare platinum resistance

thermometer of the instrumentation system and used for

recording the temperature at the orifice.

The Fluke scanner was used to sequentially display the temperature

values from each of the probes on the digital thermometer.

The HP Model 7090A was used for recording and plotting the voltage values from various transducers, typically the differential pressure transducer brought by CEESI and one of those of the instrumentation system.

The orifice static pressure transducer's voltage was monitored by the

third channel of the 7090A. This connection was made at the transducer

housing.

In addition a Daniel Industries Square Root Error Indicator Model 50

owned by NGPIA was installed in parallel with (the) CEESI Honejrwell

differential pressure transducer. The instrument failed to power up and

consequently, was not used.

II. Description of Tests and Observations

1. Observation of the Differential Pressure Transducer Calibration

Procedures

Initially a calibration pass of the 40-inch differential pressure transducers was made. This was followed immediately by a second pass to

determine the level of difference between two calibration passes closely

spaced in time. Tables lA and IB list the effects of successive calibration passes for one transducer of each span setting, i.e., 40 and 250

268
Table lA. Effects of calibrations over a three week period on

Hone3rwell differential pressure transducer HW-003

Date Run

No.

Cal.

Pass

Transducer Response Coefficients

9/26/85 449

10/08/85 529

10/15/85

10/15/85

10/15/85 541

10/16/85 557

10/17/85 563

-0.361166

-0.361730

-0.361639

-0.361554

-0.361389

-0.359589

-0.361642

0.180806

0.180901

0.181020

0.180953

0.180904

0.180583

0.180889

Date Run Cal. Calculated Diff. Pressure

No. Pass at 4 and 8 Volts in In. of Water

DP @ 4V Diff. DP (a 8V Diff.

9/26/85 449

10/08/85 529

10/15/85

10/15/85

10/15/85 541

10/16/85 557

10/17/85 563

10.032

10.027

10.042

10.037

10.036

10.051

10.028

30,.070 - 0,,005 30,,076 0,.006

0,,010 30,.105 0,.035

0,,005 30,.092 0,.022

0,,004 30,.086 0,.016

0.,019 30,.065 -0,,005

0,,004 30,.076 0,,006

Table IB. Effects of calibrations over a three week period on Honeywell differential pressure transducer HW-002

Date Run Cal. Transducer Res]ponse Coefficients

No. Pass Ao Ai A2 A3

9/26/85 449 _ -2 .24822 1.12409 0.00052559 -0,.00001533

10/08/85 529 - -2 .25591 1.12826 0.00061120 -0,.00000309

10/15/85 - 2 -2,.25335 1.12629 0.00051617 -0,,00003056

10/15/85 541 3 -2,.25694 1.12948 -0.00015505 0,,00001111

10/16/85 557 - -2,.24615 1.12342 0.00093670 -0,,00004363

10/17/85 563 - -2,,26037 1.13196 -0.00044275 0.,00002334

Date Run Cal. Calculaited Diff. Pressure

No. Pass at 4 and 8 Volts in In. of Water

DP (a 4V Diff. DP (a 8V Diff.

9/26/85 449 - 62 .496 187.588 _ 10/08/85 529 - 62,.561 0.065 187.650 0.062

10/15/85 - 2 62,.567 0.071 187.701 0.113

10/15/85 541 3 62,.597 0.095 187.710 0.122

10/16/85 557 - 62,.612 0.116 187.825 0.237

10/17/85 563 - 62,.671 0.175 187.828 0.240

269
inches of water. {Both transducers demonstrated a reproducibility of

approximately 0.09 percent or less of the full span of the response over

the three week period. Transducer response function polynomial

coefficients listed results in pressure units of psi. The conversion

factor 27.7076 inches of water at 60 °C/psi was used. Differences are taken between run 449 and the others listed.

)

2. Calibration of the Static Pressure Transducers

After calibrating the differential pressure transducers, the static

pressure transducers were calibrated. Following the data collection

procedures, the microprocessor system fit the transducer responses and

rejected these fits based on the previously set limits to the goodness

of the fit. CEESI's Mensor transducers were on-line during the period

of data collection and agreed within 0.2 psi of the deadweight tester

values

.

A second calibration pass was initiated and a difference of 2 psi

observed at the 400 psi point between the Mensor transducers and the

deadweight tester. This difference was not observed at 500 psi. The

calibration procedure was aborted due to incorrect input to the computer

system. The second static pressure calibration was begun after the

deadweight tester had been inspected. During this inspection the ball

and ball retaining cylinder were found to be excessively dirty for this

type of instrument. These were cleaned and the tester reassembled, and

the calibration procedures restarted. Although the ball was not sticking, the mensor transducers were indicating 401 psi with the deadweight

tester set for 400 psi. The tester still had something malfunctioning

and further inspections were made. It was found that the weight stack

was oscillating or chattering. Increasing the pressure to 500 psi

decreased the amplitude of the chatter significantly and the mensor

transducers indicated 500 psi within approximately 0.2 psi. It was decided to proceed with the static pressure transducer calibration procedures and to observe whether the tester chattered at the succeeding

pressures. The tester was not observed to chatter at the higher pressures, but still exhibited chatter at the 400 psi pressure point.

Tables IC and ID list the effects of successive calibration passes on

the static pressure transducers connected to the orifice meter and one nozzle. {Maximum variation relative to test run 449 for both transducers is approximately 1 psi at 775 psig.)

270
Table 2A. Effects of calibrations over a three week period on Rosemount static pressure transducer S/N 541529

(orifice static pressure)

Date Run Cal. Transducer Response Coefficients

No. Pass Ao Ai ^2 A3

9/26/85 449 - -234.013 127.468 -0.139236

10/08/85 529 - -239.116 128.980 -0.257092

10/15/85 - 2 -239.137 129.176 -0.290898

10/15/85 541 3 -235.251 127.741 -0.172472

10/16/85 557 - -232.099 127.255 -0.157710

10/17/85 563 - -230.056 126.689 -0.122678

Date Run Cal. Calculated Static Pressure

No. Pass at 4 and 8 Volts in psia

P @ 4V Diff. P (a 8V Diff

9/26/85 449 - 273.63 - 776.82

10/08/85 529 - 272.69 -0.94 776.01 -0.81

10/15/85 - 2 272.91 -0.72 775.64 -1.17

10/15/85 541 3 272.95 -0.68 775.64 -1.17

10/16/85 557 - 274.40 0.77 775.85 -0.97

10/17/85 563 - 274.74 1.11 775.60 -0.99

Table 2B. Effects of calibrations over a three week period on Rosemount static pressure transducer S/N 541528

(nozzle static pressure - position 1)

Date Run Cal. Transducer Response Coefficients

No. Pass Ao Ai A2 A3

9/26/85 449 - -241.874 126.512 -0.0379579

10/08/85 529 - -233.779 124.189 0.115094

10/15/85 - 2 -237.940 125.675 -0.0061641

10/15/85 541 3 -233.712 124.121 0.119199

10/16/85 557 - -227.491 122.939 0.174872

10/17/85 563 - -227.135 122.746 0.189841

Date Run Cal. Calculated D iff. Pressure

No. Pass at 4 and 8 Volts in In. of Water

P @ 4V Diff. P (a 8V Diff

9/26/85 449 _ 263.57 - 767.79

10/08/85 529 - 264.82 1.25 767.10 -0.69

10/15/85 - 2 264.66 1.09 767.06 -0.73

10/15/85 541 3 264.68 1.11 766.89 -0.91

10/16/85 557 - 267.06 3.49 766.21 -0.58

10/17/85 563 - 266.89 3.32 766.98 -0.81

271
3. Comparison of Parallel Connected Instrumentation

A. Differential Pressure Measurements

Observation of the differential {pressure} transducer response was done

using the HP 7090A plotting and measurement system. Input to the three

channels of the system were the following.

1. CEESI Honejrwell differential pressure transducer

2. Test loop differential pressure transducer

3. CEESI Mensor transducer connected to the orifice static

pressure (tap)

.

Observations over several time intervals were made. Most of these were taken over a 5-minute interval to match the data collection time for a single run of the data acquisition system. Figure Bl shows a plot of

the three channels taken at the same time as run 565. Two observations

can be made, (1) a periodic variation in the signal is observed, and (2)

there may be significant shifts in the differential pressure signal

during the course of a run. Both differential pressure transducers

showed very similar variation signatures. The similarity between the

two suggests that the source of the variation is common and is either

electrical, a true differential pressure variation or a combination of

both. Simple tests of the transducer response variation with the

transducers valved off and crossed over show that the source of a minor

component is electrical in nature. The variation increased

substantially when differential pressure was re-applied.

{The following section was not included in the original report. It is

given here as an explanation of the values listed in table 2.)

B. Comparison of Test Loop Instrumentation Response with the

Diagnostic Instruments

Table 3 lists the results of test parameters observed by the normal test

loop instruments and those brought to the test site for diagnostic

tests. The test runs listed were collected over a period of several

days. Generally, all of the measured parameters show good agreement

between the diagnostic instruments and the test loop instrtaments . The

values listed for the diagnostic instruments were obtained from manual

observations of the response. The test loop instrument values were obtained from the run- time sheets printed by the computer after each

test run.

272
o

>

CO

E

oi(M

cvi >" >

o p

00 o

>

o p

c\i o

>

o

o

od

CO

UJ

o

CO

Z LL

< ii^ DC O

>

p

LU

<

o

Ic

hho

a.

18°

•: "^ lii C "^

(3 ^- ^

DC d CC

h- -r- h2;

00

in;

CVJ, d

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lO200

in

OJd

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Figure Bl . Differential pressure traces taken during test run 565,

273
Table 3. Tabulation of response compar isons

Run Orif. Temp. Orif. Press. Diff. Press. Noz

.

Press.

TC RTD Mensor Rosemount CEESI* NGPIA Mensor Rosemount

(Degrees F) (Psia) (Psia) (In. of Water) (Psia) (Psia)

543 94.6 94.29 724.58 724.58 723.3 723.1

544 94.6 94.23 722.51 722.80 721.3 721.3

548 93.1 92.82 712.21 712.22 47.98 47.96

557 92.5 92.16 675.33 675.60 45.16 45.18

562 91.8 91.67 640.58 641.06 42.85 42.82

563 87.8 87.60 653.12 653.44 43.37 43.43

564 87.7 87.47 645.36 645.58 42.89 42.93

565 88.9 88.78 629.00 629.39 105 68 106.49

566 89.2 89.06 627.41 628.06 106.76 106.40

567 90.5 90.36 636.51 637.12 11.82 11 73

568 91.4 91.23 642.46 642.89 11.88 11.89

569 76.5 76.34 694.56 695.31 60.82 60.97

570 77.5 77.43 704.90 705.58 61.71 61.84

571 73.2 73.17 707.40 707.79 129.35 129.44 710.15 710.11

572 73.2 73.08 708.90 708.76 129.62 129.68 711.20 711.08

573 70.4 70.31 702.70 702.96 706.50 706.40

574 70.4 70.27 702.80 703.09 706.60 706.90

4. Chromatograph Response and Gas Standards Checks

Diagnostic tests of the chromatograph response were performed. NGPLA

made available access to a second chromatograph as part of these tests

which allowed several intercomparisons to be made. These are discussed

in detail below.

A. Amarillo Calibration Standard Gas Test

The ENCAL chromatograph located at the main office of Station 113

(Joliet) was used to test the composition of the Amarillo Gas Standard.

The cylinder containing the standard gas had been taken to the

chromatograph at the main office by NGPLA personnel prior to this visit.

(The results of that test are included here as a form of documentation

of NGPLA' s efforts to identify sources of error in the measurement

systems and procedures). This instrument {located in the main office}

used a gas standard prepared to NGPLA' s specifications for Station 113

with a composition between the Gulf Coast and Amarillo gas compositions.

Table 3 gives the measured and manufacturer specified compositions for

the Amarillo gas standard prepared for this project.

274
Table 4,

Component Specified Com

C6 + 0.1001

Nitrogen 2.701

Carbon Dioxide 0.5990

Methane 91.3973

Ethane 3.7516

Propane 1.001

Isobutane 0.1500

Normal Butane 0.0999

Isopentane 0.1001

Normal Pentane 0.1000

Measured Composition

0.09714

2.6573

0.5833

91.5547

3.6633

0.9995

0.1515

0.0986

0.0995

0.1013

B. Tests of Test Loop ENCAL Chromatograph Response

The initial test objective was to determine the amount of change in the

composition of the test gas measured by the test loop ENCAL induced by

using one of the calibration gases with the opposite test gas, i.e., the

Amarillo calibration gas for the chromatograph standard with the test

loop running Gulf Coast gas. For this test the test loop was blocked so that there was no flow in the loop. In this way the gas being tested by

the chromatograph would be stable in composition. Then both calibration

gases were used in succession to perform several composition meas- urements of the test gas. Differences between the two composition meas- urements would then give an estimate of the effect on the gas properties

of operating the chromatograph in this way as has been done during the

1985 testing at Joliet. Table 5 lists the test gas composition using

both calibration gas standards.

275
Table 5. Test gas compositions us ing both calibration

standards on the test loop ENCAL chromatograph

Date: 10/16 10/16 10/16 10/16 10/16 10/16 10/16

Time: 12:22 12:34 12:47 14:04 14:16 14:29 14:42

Callb. Gas Gulf

Coast

Gulf

Coast

Gulf

Coast

Amar. Amar. Amar. Amar.

Component

C6 + .02906 .02946 .02926 .02937 .02912 .02906 .02910

Nz .36384 .36619 .36057 .34768 .34613 .34986 .35015

Methane 95.68430 95.67700 !?5. 66610 95 .6118 95 .6142 9^L6058 95 .61020

CO2 .69508 .69276 .69574 .70943 .70931 .70977 .70966

Ethane 2.31571 2.31875 2.32698 2 .37968 2 .37820 /1.37853 2 .37860

Propane .55849 .56063 .56356 .56730 .56510 .56504 .56497

I -Butane .14005 .14008 .14142 .14032 .13982 .13979 .13955

N- Butane .12443 .12592 .12680 .12659 .12790 .12932 .12889

I-Pentane .05607 .05563 .05475 .05286 .05710 .05772 .05680

N-Pentane .03296 .03355 .03478 .03499 .03315 .03511 .03392

BTU 1033.9 1034.0 1034.2 1034.6 1034.6 1034.7 1034.6

S.G. .5864 .5864 .5865 .5869 .5869 .5870 .5869

C. Composition of Test Loop Gas Taken From a Sample Cylinder

A sample of gas was taken from the test loop (Gulf Coast was the gas

type) in one of the stainless steel sample containers supplied by Mr.

Fling. It was analyzed on both ENCAL chromatographs located at the test

site. One was the ENCAL located at the test loop and the other was the

main office ENCAL chromatograph used in the tests described in section A

above. Table 5 gives the results of several analyses using the main

office ENCAL which had as its standard the specially prepared mixture

made by Matheson. This sample bottle was then brought to the test loop

and connected to the ENCAL there which had been calibrated with the

Amarillo gas standard. Table 7 lists successive compositions for the

gas drawn from this sample bottle.

276
Table 6. Sample bottle of Gulf Coast gas analyzed by encal

in office using Matheson calibration gas

Date: 10/16 10/16 10/16 10/16

Time: 1342 1356 1410 1424

Calib. Gas Matheson Matheson Matheson Matheson

C6 + .05115 .05631 .05898 .06000

Nitrogen .44034 .37154 .35358 .35433

Methane 95.57980 95.62870 95.63170 95.6288

CO .65523 .65580 .65671 .65876

Ethane 2.35533 2.36082 2.37018 2.37177

Propane .57128 .57399 .57387 .57491

I -Butane .13912 .14097 .14097 .14076

N- Butane .12522 .12680 .12654 .12780

I-Pentane .50135 .05120 .05247 .05195

N-Pentane .03112 .03387 .03494 .03088

BTU 1034.8 1036.0 1036.4 1036.3

S.G. .5871 .5871 .5872 .5872

NOTE: This sample bottle to be sent to Wayne Fling for further

analysis

.

Table 7. Sample bottle of Gulf Coast analyzed on encal

at test loop (using Amarillo calib. gas) after sample

analyzed in office

Date: 10/16 10/16 10/16 10/16 10/16 10/16 10/16

Time: 15:07 15:20 15:33 15:46 15:58 16:11 16:24

C6 + .02278 .02479 .02578 .02685 .02761 .02885 .02902

Nitrogen .44798 .39926 .37451 .36632 .36331 .35495 .35222

Methane !95.53660 95.57170 95.59830 95.60120 95 59620 95.6032 95 60910

CO .70705 .70859 .70737 .70784 .70888 .70963 .70962

Ethane 2.37331 2.37654 2.37427 2.37389 2.37983 2.37923 2.37566

Propane .56143 .56233 .56370 56457 .56554 .56487 .56468

I -Butane .13807 .13891 .13926 .13956 .13933 .13950 .13978

N- Butane .12652 .12733 .12823 .12877 .12864 .12882 .12864

I-Pentane .05432 .05711 .05544 .05712 .05700 .05714 .05769

N-Pentane .03198 .03339 .03310 .03388 .03367 .03383 .03362

BTU 1033.1 1033.8 1034.1 1034.4 1034.4 1034.6 1034.6

S.G. .5869 .5869 .5868 .5869 .5869 .5869 .5869

277
5. Comparison of DDR-6000 Response to the Ametek RK-300.

The Ruska DDR-6000 response was tested at atmospheric pressure using the

Ametek deadweight tester. The test sides of both instruments were con- nected together. Nitrogen was used as the pressure source for the deadweight tester. The manufacturer's accuracy specification for the Ametek

used is 0.015% for differential pressures greater than 30 inches of

water and 0.025% for differential pressures less than 30 inches. Table

8 gives the results of this test.

Table 8. DDR- 6000 calibration

2nd test

Obs Ametek DDR DDR Zero Actual DDR Diff

Press. Indication Adjusted Diff. Press. Press.

(In. Water) (Volts) (Volts) (In. Water) -- (In. Water) --

1 0.01529 0.0000 0.000 0.000 .000

2 10 0.23376 0.24906 9.998 10.009 + .011

3 20 0.48255 0.49785 19.995 20.007 +0.15

4 50 1.2290 1 . 2443 49.988 50.004 +0.16

5 100 2.4729 2.4882 99.976 99.992 +0.16

6 150 3.7169 3.7322 149.964 149.984 + .020

7 200 4.9608 4.9761 199.952 199.973 + .021

8 250 6.2050 6.2203 249.940 249.973 + .033

9 200 4.9608 4.9761 199.952 199.973 + 021

10 100 2.4730 2.4883 99.976 99.996 + .020

11 20 0.48260 0.4979 19.995 20.009 + .014

12 20 0.01530 0.000 0.000 0.000 .000

6. Thermocouple Measurement Results

Table 9 gives the temperatures of the thermocouples at the four installations given in the auxiliary equipment section. {The water temperature

refers to the upstream, heated water bath, the skip temperature is that

obtained from a thermocouple mounted on the meter tube surface, the

upstream gas temperature is measured by an insertion thermocouple in a thermometer well upstream of the Sprenkle flow conditioner, and the

orifice temperature was taken from the test loop instruments.)

278
Table 9. Temperature vs. time

CEESI thermocouples

10/16/85 Flow Through the FE-7/8-1B Plate

Time Water Skin Upstream Gas Orifice

Temp, Temp. Temperature Temp.

7:30 113.0 86.0

8:10 130.0 93.0

8:24 129 9 89.5 95.4 92.2

8:40 127.8 89.4 95.3 92.0

8:55 127.0 89.1 94.7 91.8

9:25 125.8 89.4 94.7 91.5

9:42 125.0 89.5 94.8 92.2

12:35 121 3 89.5 93.3 91.6

1:35 119.8 90.9 92.6 91.3

*2:00 118.8 88.7 91.9 84 5

2:30 116.0 86.0 90.2 81.5

10/17/85 Flow through 6B Plate

1:30 150.0 74.7 74.6 74.7

1:40 161.0 77.3 77.2 77.3

2:00 167.3 73.7 73 2 73.3

2:10 171.0 73.4 73.1 73.2

2:30 168.8 70.5 70.5 70.5

2:45 171.9 70.9 70.4 70.4

*Line Shut-in for ENCAL Evaluation at 2:00 PM.

Comparison of Compressibility Factor Values For Selected Gas

Compositions

Tables 10-12 list compressibility and supercompressibility factors for

the test gas compositions obtained from the test loop ENCAL chromatograph for both calibration gases . The differences between the two

types of calibration gas for the same test gas is the source of a change

in the compressibility and supercompressibility factors of below 0.02%.

Table 12 gives these factors calculated for the composition in table 11

but with the C5+ fraction set to zero. Neglecting the C5+ fraction

induces a systematic change in the values of these factors of at most

0.03%.

279
Table 10. Gulf Coast test gas using gulf coast calibration

gas taken on Oct. 15, 1985 at 12:47 using the

test loop ENCAL chromatograph

Compressibility Factors

essure Temperature CF)

psia 50 60 70 80 90 100

400 9371 9415 0.9455 9493 9527 9560

450 9293 9343 0.9389 9431 9470 9506

500 9215 9271 0.9322 9370 9413 9454

550 9138 9200 0.9256 9309 9357 9402

600 9061 9129 0.9191 9248 9301 9350

650 8985 9059 9126 9189 9246 9299

700 8909 8989 0.9062 9130 9192 9249

750 8834 8920 0.8999 9071 9138 9199

800 8760 8852 8937 9014 9085 9151

850 8687 8785 0.8875 8957 9033 9103

Computed Supercompressibility Factors Fpy

Pressure Temperature (°F)

psia 50 60 70 80 90 100

400 1.0319 1 .0295 .0273 1.0253 0234 .0217

450 1.0362 1 0335 .0309 1 0286 0265 .0245

500 1 0406 1 .0374 .0346 1 0320 .0296 .0274

550 1 0450 1 .0415 .0383 1.0353 .0327 .0302

600 1.0494 1 .0455 .0419 1.0387 0358 .0331

650 1.0538 1 .0495 .0456 1.0421 0388 0359

700 1.0583 1 .0536 .0493 1.0454 0419 .0387

750 1.0628 1 .0576 .0530 1.0488 0450 .0415

800 1.0673 1 .0617 .0567 1.0521 0480 .0442

850 1.0718 1 .0658 0603 1.0555 0510 0470

Measured Gas Composition

Nitrogen 0.3606 N Butane 0.1268

Carbon Dioxide 0.6957 IsoButane 0.1414

Methane 95.6661 N Pentane 0.0348

Ethane 2.3270 IsoPentane 0.0548

Propane 0.5636 Ce+ Average 0.0293

280
Table 11. Gulf Coast test gas using Amarillo calibration

standard taken on Oct. 16, 1985 at 14:42

using the test loop ENCAL chromatograph

Pressure Temperature (°F)

psia 50 60 70 80 90 100

400 1 9370 9414 0.9455 9492 9527 9559

450 9292 9342 0.9388 9430 9469 9506

500 1 9214 9270 0.9321 9369 9412 9453

550 1 9137 9199 0.9255 9308 9356 9401

600 1 9060 9128 0.9190 9247 9300 9349

650 1 8983 9057 0.9125 9187 9245 9298

700 1 8908 8988 0.9061 9128 9190 9248

750 8832 8919 8997 9070 9136 9198

800 8758 8850 0.8935 9012 9083 9149

850 1 8684 8783 0.8873 8955 9031 9101

Computed Supercompressibility Factors, Fpy

Pressure Temperature (°F)

psia 50 60 70 80 90 100

400 1.0319 0295 0273 1.0253 1.0234 1 0217

450 1.0363 0335 0310 1.0287 1.0265 1 0246

500 1.0406 0375 0346 1.0320 1.0296 1 .0274

550 1.0450 0415 0383 1.0354 1.0327 1 .0303

600 1.0495 0456 .0420 1.0388 1.0358 1 .0331

650 1.0539 .0496 .0457 1.0422 1.0389 1 .0359

700 1.0584 .0537 .0494 1.0455 1.0420 1 .0388

750 1.0629 .0577 0531 1.0489 1.0451 1 .0416

800 1.0674 .0618 .0568 1.0522 1.0481 1 .0443

850 1.0719 .0659 .0605 1.0556 1.0511 1 .0471

Measured Gas Composition

Nitrogen 3501 N- Butane 0.1289

Carbon Dioxide 7096 IsoButane 1398

Methane 95 6082 N-Pentane 0.0339

Ethane 2 3786 IsoPentane 0.0568

Propane 5650 Cg+ Average 0.0291

281
Table 12. Compressibility and supercompressibility

computed for the same gas composition as in

table 9 with the Cg+ fraction set to zero and the composition renormalized

Pressure

psia

400

450

500

550

600

650

700

750

800

850

Temperature ("¥)

50

0.9373

0.9296

0.9218

0.9141

60

0.9417

0.9345

0.9274

0.9203

70

0.9457

0.9391

0.9325

0.9259

80

0.9495

0.9433

0.9372

9311

90

9529

0.9472

0.9415

0.9359

0.8989 0.9062 0.9130 0.9192

0.8913 0.8993 0.9066 0.9133

0.8839 0.8924 0.9003 0.9075

0.8765 0.8856 8940 0.9017

0.8691 0.8789 0.8879 8961

100

0.9561

0.9508

9456

0.9404

0.9065 9132 0.9194 0.9251 0.9304 9352

0.9249 0.9302

9195 0.9252

0.9141 9202

0.9088 0.9154

0.9036 0.9106

Computed Supercompressibility Factors, Fpv

Pressure Temperature CT)

psia 50 60 70 80 90 100

400 .0318 .0294 1.0272 0252 .0233 .0216

450 .0361 .0333 1.0308 0285 0264 .0244

500 0404 0373 1.0345 0319 0295 .0273

550 .0448 0413 1.0381 0352 0326 .0301

600 .0492 0453 1.0418 0386 0356 .0329

650 .0536 0493 1.0455 0419 0387 .0357

700 .0581 0534 1 0491 0453 0418 .0385

750 .0625 0574 1.0528 0486 0448 .0413

800 .0670 0615 1.0565 0519 0478 .0441

850 .0715 0655 1.0601 0552 .0508 .0468

The gas composition is the same as that

of Table 9 except for the C5+ fraction

which is set to zero and the composition renormalized.

Gas Composition

Nitrogen 0.3607 N- Butane 0.1268

Carbon Dioxide 0.6959 IsoButane 0.1415

Methane 95.6940 N-Pentane 0.0348

Ethane 2.3277 IsoPentane 0.0548

Propane 0.5638 C6 + 0.0

282
8. Differential Pressure Signal Quality

The quality of the differential pressure signal was observed throughout

this set of tests. The method used was plotting of the differential

pressure transducer signals such as is shown in figure 1. The variation

in differential pressure signals seen in the plots is rather low in

frequency. The effects of higher frequency components in the gas pressure could not be observed directly by the instrumentation available in

this work. If such high frequency pressure waves are present in the

pipeline and test loop, their effect on the response of the transducers

and their associated piping is not known and is not measurable with the

present instrumentation system. However, a change in the response of

the differential pressure transducers might be seen for differing conditions of the test loop or for the pipeline system around the Joliet

station. A change in conditions would be expected to change characteristics {and frequency) of the pressure waves in the system if these were

present. As a test of this assumption a change in the pipeline configuration upstream of the station was done during a data collection pass

consisting of four runs.

a. Pipeline Condition - An initial data collection pass of four runs was made with the pipeline operating in its normal condition at that

time in which gas was being fed to the Howard St. Line through two

8-inch valves located 1/4-mile from the station. Station personnel

stated that these were small valves for the flow rate being sent to

Howard Street. It could be assumed that the level of acoustic noise

in the pipeline induced by these valves would be higher with them

open than with them closed.

b. The two 8 -inch valves were shut and the second data pass was begun.

No changes were made in the test loop conditions. During the fourth run in the pass, the valves were opened. The results of this test

are given in table 13.

Table 13 lists results for the initial data collection pass of four runs which were run numbers 549 through 552. The valves were closed during

runs 553 - 555. These are marked by the asterisks in the table. The

difference in variation in the results are quite substantial. The range

of variation in the differential pressure values decreases by approximately a factor of 3. The variation in the discharge coefficient for

the four initial runs is 0.35% relative to 0.11% for the three runs taken with the valves off. The variation in the signals increased as the valves were opened. These data were collected using the 0.1 beta

ratio plate of the 6 -inch meter run.

283
Table 13. Observed pipeline disturbance effects

Run Orifice Reynolds Discharge Diff, Press. Range of

No. Press. Number Coefficient Diff. Press,

(Psi) (In. Water) (%)

549 555.4 228,511 0.5959 37.388 17.51

550 557.8 229,587 0.5967 37 448 21.66

551 560.3 230,583 5947 37.875 17.69

552 563.2 231,720 0.5968 37.817 18.13

553* 580.9 239,140 0.5948 39.288 6.98

554* 587.6 241,943 0.5952 39.688 6.97

555* 593.9 244 , 544 0.5955 40.087 6.33

556 598.3 246,488 0.5977 40.089 12.87

* Eight- inch valves closed during this run

A similar test of the system was made with the 0.75 beta ratio plate

installed in the meter run, in which a main shut off valve upstream of

the meter run in the test loop was partially closed in an attempt to

isolate the orifice meter somewhat from pipeline noise or disturbances.

Minimal change in the discharge coefficient values for the fully open or partially closed condition of the valve were observed.

Near the end of the tests it was suggested by NGPIA personnel that damping the transducers may have an effect on the differential pressure

values and consequently the discharge coefficient values. After the

authors left the site the damping of the transducers was changed sequentially and data collected for each value. The damping time constants

used were 0.3, 1.0, 2.0, and 5.0 seconds. Normally the transducers have

been operated with no damping. Minimal change in the discharge

coefficient values were observed as the damping time constant was

changed.

III. Conclusions

With the use of redundant measurements made during this evaluation, the

instrumentation system at the Joliet Test Site is operating within its

expected specifications. All calibration procedures used by the NGPLA

operating personnel are adequate and are being followed correctly. At

this time quantitative evaluation of the effect of the original computational method agreed by the committee for this project relative to one based on Starling's recent publication of AGA Draft Report No. 8 cannot

be performed until critical flow factor calculations based on Starling's

method are complete. The originally agreed method utilizes NX- 19 for

computation of the gas properties at the orifice and Johnson's method

for calculation of mass flow rate through the nozzle. Preliminary

calculations of the compressibility factors using the three methods show

that the difference between Johnson's and Starling's compressibility

values for the same gas composition differ. The magnitude of the

difference may be significant to the results obtained to date. As an example the following calculation was made for Run No. 563.

284
Orifice Pressure - 653.44 Psia Nozzle Pressure - 653.57

Temp. = 87. 60^ Temp. = 85.12°F

Starling Z = 0.92356 Starling Z = 0.92214

NX-19 Z = 0.92702 Johnson Z = 0.92129

Starling Z - NX-19 Z = -0.00346

Starling Z - Johnson Z = +0.00085

It is expected that the use of a unified method for calculation of the

gas properties for the test data will result in improved results and may

reduce the scatter in the results since the differences between NX. 19

and Johnson's methods relative to Starling will be pressure, temperature

and composition dependent. The above example shows that changes of

approximately 0.4 percent may be seen if the proper gas property calculation is performed.

IV. Recommendations

1. It is recommended that further testing at the site be limited to high

differential pressure values, i e., 50, 100, and 200 inches of water.

2. Although gas property effects induced by measured compositional

changes in the gas appear to be minimal in the compressibility

factors, the magnitude of the effect of these changes on the critical

flow factor is not yet known for values based on the recent

correlation of Starling in AGA Draft Report No. 8. The computational

capability to calculate the critical factor value is being pursued by

Dr. Whetstone. When these calculations can be made they will be, and

an addendum to this report will be made.

This report was presented to the Orifice Steering Committee. No single

source of variation in the measurement system could be identified as being sufficiently large to cause the offset in the results between the

data taken in 1984 and 1985. Approximately a month of testing was performed after these diagnostic tests were completed in the hope that

the source of the systematic effects could be isolated at a latter time

and appropriate corrections applied to the data during analysis. No

such source was identified.

285
References

Bl. Whetstone, J. R. , Cleveland, W. G. , Baumgarten, G. P., Woo, S.,

and Croarkin, M. C. , "Measurements of Coefficients of Discharge

for Concentric Flange-Tapped Square-Edged Orifice Meters in Water

Over the Reynolds Number Range 1,000 to 2,700,000", NBS Report to

be published.

B2. Certain commercial equipment and instruments are identified in this

paper in order to describe the experimental procedures and results

adequately. In no case does such identification imply

recomendation or endorsement by the National Bureau of Standards

nor does it imply the material or equipment is necessarily the

best available for the purpose.

286
APPENDIX C

Derivation of the Coefficient of Discharge Relation and

Associated Units Conversion Factors

A, Theoretical Mass Flow Rate

The arrangement of an orifice meter placed in a pipeline with

differential pressure taps located in the adjacent flanges is

illustrated in figure CI. The derivation of the theoretical mass flow

rate is based on the following assumptions:

1. the velocity profile is uniform (one -dimensional) with no boundary layers at the pipewall or the surface of the orifice

plate

,

2. the pipeline is horizontal and of uniform, circular

cross section, and

3. no energy loss occurs between the pressure taps.

The parameters used in the derivation are:

P^ = pressure at the upstream orifice tap,

V^ = average velocity in the pipe upstream of the orifice plate,

D = diameter of the meter tube

,

Aj^ = 7rD^/4 = area of the meter tube through which the fluid

flows

,

P2 = pressure at the downstream orifice tap,

V2 = average velocity of the fluid through the orifice,

d = diameter of orifice

A2 = 7rd^/4= area of the orifice,

mj^ = mass flow rate through the meter tube,

mg = mass flow rate through the orifice,

p^ = density of the fluid flowing in the meter tube,

P2 = density of the fluid flowing in the orifice,

fi = d/D, the orifice beta ratio,

u = internal energy of the flowing fluid per unit mass,

h = enthalpy of the flowing fluid per unit mass,

s = entropy of the flowing fluid per unit mass,

R = universal gas constant,

T = absolute temperature,

Cp = specific heat of fluid at constant pressure,

Cy = specific heat of fluid at constant volume,

7 = Cp/Cy , the ratio of specific heats,

r = P2/P1, the ratio of the pressure at the upstream pressure

tap to that at the downstream pressure tap,

AP = P;^-P2, the differential pressure developed across the

orifice meter.

287
a

CO

Figure CI. Orifice meter installation in a pipeline

288
The physical principles needed to derive the mass flow rate are the

continuity equation (conservation of mass) and the energy equation

(conservation of energy)

.

The mass flow rate of fluid passing through the meter tube or the

orifice may be expressed as a function of the average fluid velocity, V,

the area of the tube or orifice, A, and the density of the fluid, p\

m = pAV. (C.l)

The continuity equation requires that

mj^ = m2 , ( C . 2

)

or

^lAiVi = PaAaVz- (C.3)

The energy equation relates the properties of the flowing fluid at

position 1 to those at position 2. In SI units.

Pi 1 P2 1 — + - Vi2 + ui + gZi = — + X V22 + U2 + gZ2 , (C.4)

Pi ^ Pz ^

where Z^ and Z^ are the elevations of the points at which the

pressures are measured and g is the local acceleration due to gravity.

With the assumption that the pressure taps are at the same elevation,

one can rewrite this in terms of the enthalpy per unit mass:

W + I

Vi2 = h2 + I

V22. (C.5)

Eliminating V^^ using eq (C.3) and forming P2^2^Z' °^^ obtains the

theoretical mass flow rate in the form:

m = (p2^dV4)[2(hi-h2)]^/2[i_^4(^^/^^)2j-i/2_ (C.6)

289
To proceed further, one needs to express the enthalpy difference, hj^ -hg , in terms of parameters that are either measured or calculated. If it is

assumed that the fluid is an ideal gas , then

P/P = RT, (C.7)

where R is the universal gas constant and T is the absolute temperature,

With the assumption that the change in state of the fluid between the

pressure taps is reversible and adiabatic, one also has

p^/p^T = V^/Pz'' = ^/P'' = constant = c, (C.8)

where 7 is the ratio of the specific heats. Using this equation, one can integrate the thermodynamic relation (3h/3P)g = 1/p = c/P^^"" to

obtain

hi-h2 = c ^ p^(7-i)/7[i-r(7-i)/7]^ (C.9)

where r = ^2/^1 ^^ ^^^ ratio of the pressure at the downstream pressure

tap to that at the upstream pressure tap.

Combination of eq (C.9) and (C.6) leads, upon rearrangement, to an expression for the theoretical mass flow rate in terms of the

differential pressure, AP = Pj^-P2, developed across the orifice meter:

where

Y = ^2/7

272 (1-;0M^^^

7 i-r^'i-'i-)/i i-^<

7-1 1-r l-yS'-r^/T

(C.ll)

Here Y is the adiabatic expansion factor, which depends on the diameter

ratio, b, the pressure ratio, r, and the ratio of specific heats, 7.

The value of p^ in eq (C.IO) should be computed at P;^ > '^1 using the

general equation of state of the actual gas.

Equation (C.ll) is generally applicable to flow element geometries where

the radial expansion of the fluid is confined by the shape of the

element, i.e., in nozzles and Venturis. However, the abrupt geometries

of orifices allow expansion of the gas radially as well as longitudinally, and the adiabatic conditions assumed in developing eq

(C.ll) do not apply for orifices. An empirical method for determining

the expansion factors for orifices was developed by Buckingham [Cl] and

290
modified by Bean and is the widely used basis for calculation of

expansion factors for orifice flows. This method is contained in API

2530/AGA 3 for up stream and downstream static pressure taps for the

flange tapped orifice meter. This relation, eq (C.12), was used in

analyzing test run results.

Y2 = [1 + X2]^/2 _ (0.41 + 0.35/3M X2/[k(l + X2 ) ] (C.12)

where X2 = the ratio of differential pressure to absolute static

pressure at the downstream tap.

B. Orifice Thermal Expansion Factor

Most materials expand or contract as their temperature increases or decreases. Consequently, a factor, F^ , must be introduced to correct

the area of the orifice when the operating temperature differs

appreciably from that at which the area was determined. This is done by

replacing d^ in eq (C.IO) by F^d^.

C. Definition of the Discharge Coefficient

The derivation of eq (C.IO) is based on the assumptions given at the

beginning of this Appendix. The derivation neglects many effects that occur in actual orifice meter configurations, e.g., effects due to

non-uniformities in the velocity profile , turbulence, frictional

losses, orifice edge sharpness, the finite thickness of the orifice

plate, pressure tap location, etc. The inability to model these effects

realistically results in a significant difference between the actual mass flow rate through an orifice meter and that predicted theoretically

(eq 10) . One corrects for this difference by introducing a correction

factor defined as the ratio of the actual mass flow rate to the

theoretical mass flow rate given by eq (C.IO) modified to include the

orifice thermal expansion factor. This ratio is customarily called the

coefficient of discharge, or the discharge coefficient, and denoted by

Cjj . From eq (C.IO), C^j is given by

C, = m(l-/3^)i/2

272 YF^(PiAP) 1/2 (C.13)

Because C^ is a ratio, the value of C^ is independent of the system of

units in which the various quantities are measured.

D. Unit Conversion Factors

Because the quantities in eq (C.12) are often measured in incommensurate

units, it is customary to replace the factor of n/2j2 in the definition

of the discharge coefficient by a factor, N, which depends on the actual

units used. With this replacement, eq (C.12) is identical to eq (1) in

section II.

291

APPENDIX D

Report to the American Petroleum Institute

on Experimental and Computed Values

of

Natural Gas Compressibility for Samples of Gas Similar

to Those Used in the Joliet Orifice Meter Testing Program

The report reproduced here was submitted to the American Petroleum

Institute by the University of Oklahoma. It is reproduced here in

keeping with the intent of NBS and API to document this orifice test

program as completely as practicable. No alterations have been made to

the report with the exception of placing page numbers on each page of

the textual portion of the report to be consistent with the page

numbering system of this doctoment. The original report contained

voluminous tables in various of the appendices. These tables have not

been reproduced here. The appendices containing comparision of

experimental and calculated values have been included.

293
FINAL REPORT TO

AMERICAN PETROLEUM INSTITUTE

ON

CONTINUED EXPERIMENTAL AND ANALYTICAL SERVICES

IN SUPPORT OF

THE API NATURAL GAS FLOW TEST PROGRAM

By

Rex T. Ellington, Investigator

Kenneth E. Starling, Investigator

Mark J. Hill, Laboratory Supervisor

Jeffery L. Savidge, Research Associate

School of Chemical Engineering and Materials Science

University of Oklahoma

Norman, OK 73019

May 15, 1986

294
TABLE OF CONTENTS

SUMMARY

Introduction Page 1

Experimental Data Page 2

Computation Work Page 3

Interpolation Tables Page 4

References Page 6

65th Annual Meeting GPA Paper Page 9

APPENDICES

A. Experimental Compressibility Factors, Wet

Amarillo Gas, 288.71 and 299.85 K

B. Experimental Compressibility Factors, Dry

Gulf Coast Gas, 288.71 and 299.85 K

C. Comparison of Calculated and Experimental

Compressibility Factors, Wet Amarillo Gas

D. Comparison of Calculated and Experimental

Compressibility Factors, Dry Gulf Coast Gas

E. Calculated Compressibility Factors, Wet

Amarillo Gas

F. Calculated Compressibility Factors, Wet

Gulf Coast Gas

G. P-T Diagram For Wet Amarillo Gas

Critical Flow Factors For Wet Amarillo Gas

Mass Flowrate Comparisons (OU/GRI vs Johnson)

H. P-T Diagram For Wet Gulf Coast Gas

I. Interpolation Tables For Z and C*, Both Gases

295
FINAL REPORT ON

CONTINUED EXPERIMENTAL AND ANALYTICAL SERVICES

IN SUPPORT OF

THE API NATURAL GAS FLOW TEST PROGRAM

SUMMARY

INTRODUCTION

Pursuant to a proposal presented by the University of

Oklahoma on August 15, 1985, a contract for continued work

to support API's test program was signed on November 12,

1985. Under this contract, the Investigators were obligated

to carry out the following work:

1. Two evacuated cylinders were to be sent to NGPL to

be filled with gas from the pipeline under test.

One cylinder will be sent to Cities Service for

analysis and the other will be sent to O.U. for

compressibility factor measurements. (This gas

became known as the Amarillo gass.)

2. Information supplied by API regarding composition

variation of the pipeline gas will be tabulated

with respect to composition. Compressibility factor and C* calculations will be performed for the

maximum, minimum and average compositions of both

the Gulf Coast and Amarillo gas compositions supplied by API on July 12, 1985. However, these compositions must be modified to include water content. Efforts will be made to develop simple

interpolation tables for interpolating compressibility factor and C* variations from the test gas

furnished to OU and the limits of variation defined

by compositions supplied by API. Accuracy sought

for the interpolation tables will be equal to or

better than the guaranteed discharge coefficient

for the flow nozzle, i.e., 0.1%. Estimation of

accuracy will be included with the tables.

3. Compressibility factor data runs are to be made

with O.U.'s Z-Meter in 50 psi increments from 150

psi to cylinder pressure at nominally 60 F and 79

F. One duplicate run is to be made at each pressure and temperature with a difference in Z of no

greater than 0.05%. Cryogenic compression will be

296
used to obtain data in the 500 to 900 psi range.

The composition supplied by API, including water

vapor will be used to calculate the compressibility

factor for each data point and compared with the

experimental value and reported.

Compressibility factor tables will be computed

for the test gas for 1 psi and 0.5 F intervals up

to 600 psi. A C* table will be developed for the

same increments of temperature and pressure. The

estimated dew point curve for the experimental gas

for the range of interest. The outlet nozzle conditions for a number of inlet conditions will be

plotted to show when condensation could occur.

The composition of the gas was supplied by API but was found

to be in error. The correct composition is given in Table

1, Appendix A.

EXPERIMENTAL DATA

The experimental equipment and procedures are exactly the

same as reported in the April 15, 1985 report on the first

part of the API work. Oral presentation of the accuracy and

precision of the work was made at steering committee meeting

in Tulsa, Dec. 5, 1985. A request was made that some of

this information be included in the final report. O.U.

agreed to this inclusion and is providing it in the form of

the attached reprint of a paper presented at the annual GPA

meeting. In this way, it can be done without cost. The

purpose of this inclusion is to assure API that the quality

of the data is that of the best research data. One factor

worth noting is that the precision of the data has improved

from +/- 0.03% to +/- 0.02% from the first API test to the

second.

The primary data for the new test work are presented in

Tables 1 and 2, and the accompanying precision plots are

given in Figures 1 and 2, Appendix A. It should be noted

that more tests than the one replication specified by the

contract has been made in every case (also at no cost to

API). Runs were usually repeated if they differed by more

than 30 parts in 100,000. This is significantly less difference than the 0.05% stipulated in the proposal.

The data in Tables 1 and 2 are for the pipeline gas on the

wet basis of 5.4 lb. H20 water per MMSCF supplied by API.

All subsequent calculations were performed on this basis.

When compressibility factors were calculated for the

297
original analysis supplied by API, converted to a wet basis,

the difference from the experimental values was considerably

greater than normally found. A careful reanalysis was performed by Cities Service and the agreement became very good,

as can be seen from Table 5. From this it can be seen that

inaccuracies in composition analysis can result in undesireable errors in calculated compressibilities. The final wet

basis composition for the gas is given at the top of Tables

1 and 2.

For sake of completeness, the experimental compressibility

factor data for the dry Gulf Coast gas are repeated in

Tables 3 and 4, and Figures 3 and 4, Appendix B. The gas

composition is given at the top of each table.

COMPUTATION WORK

During discusssion of changing API's chromatographic

analysis to a wet basis, it was discovered that a communication error had occurred during the early 1985 work on the

Gulf Coast gas. All data and calculations were reported for

the cylinder of test gas supplied by API, per the proposal.

A Committee member pointed out the need for calculations to

be made for the wet flowing gas with an average water content of 4.6 lb H20 per MMSCF. To maintain the quality and

utility of our work, O.U. recalculated both the compressibility factor and C* values for the Gulf Coast gas. This

work was done without charge to API.

Comparison of the calculated compressibility factors with

the experimental values for the wet Amarillo gas is given in

Table 5, Appendix C. All deviations are less than 0.1% and

most are less than 0.05%. Again the excellence of the

OU/GRI correlation was proven.

For completeness, comparison of the calculated and experimental values for the Gulf Coast gas are given in Table 6,

Appendix D. This can only be on the dry basis because the

gas supplied by API for the test work was dry. This work

was done without charge.

The calculated values of the compressibility factor for the

pressure and temperature increments agreed upon are

presented in Table 7, Appendix E, for the wet Amarillo gas.

These values were calculated using the OU/GRI correlation.

298
The new calculated values of the compressibility factor for

the pressure and temperature increments agreed upon are

presented in Table 8, Appendix F, for the wet Gulf Coast

gas. This work also was performed without charge.

The dew point curve for the wet Amarillo gas is presented in

Figure 5, Appendix G. Expansion calculations were performed

to determine whether a given set of conditions might result

in condensation. To use the figure, select the condition of

interest in the column of lettered points to the right. The

outlet condition is represented by the same letter in the

same row in the left hand column of letters. From the figure, it can be seen that the chance of condensation is very

slight for the inlet pressures available. Only the lowest

temperatures at the highest pressures should be of concern.

The calculated C* values for the wet Amarillo gas are

presented in Table 9, Appendix G. At the end of this Appendix are Tables 9a and 9b, which give mass flow rate comparisons between the OU/GRI correlation result and the Johnson tables for both the Amarillo and Gulf Coast gases.

Similarly, the dew point curve for the wet Gulf Coast gas is

shown in Figure 6, Appendix H. The calculated values differ

so slightly from those reported earlier that this table is

not repeated.

INTERPOLATION TABLES

Given the range of composition, heating value, and gravity

supplied by API for the Amarillo gas and Gulf Coast gas,

interpolation functions were developed in the following

manner.

1). The condition at which the compressibiliity factor and

critical flow factor would change most for change in the

variable was selected to determine whether gas composition,

heating value, or specific gravity would be best for

developing interpolation equations. This condition was found

to be the lowest temperature, highest pressure condition for

the range of the calculations to be made (50 deg. F and 700

psia.). The best variable was found to be the heating

value.

2). Compressibility factor and critical flow factor values

were calculated using the OU/GRI equation of state for each

299
of the compositions supplied by API and plotted versus pressure for both types of gas. Then Z and C* values were plotted versus heating value to determine the functional form

that could be used for interpolation. It was observed for

both gases that a nearly linear relationship exists between

the heating value of the gas and the critical flow factor

and the same for compressibility factor at constant temperature and constant pressure conditions. This relationship

holds within the targeted uncertainty.

3). A linear function of pressure and heating value was

selected to model the critical flow factor and the compressibility factor for each isotherm. That is, Z = A + B*HV + C*P and C* = K + L*HV + M*P. The variation of C* was noted

to be less than the variation of Z for the range of conditions under consideration.

4). Data for Z and C* were generated for interpolation purposes using the OU/GRI equation of state at five (5) heating

values for temperatures from 40 to 110 degrees F and pressures from 360 to 740 psia for both the Amarillo gas and the

Gulf Coast gas. The range of heating values covered the

range supplied by API to insure that the interpolation equations were applicable to all of the gases under consideration. For the Amarillo gas, the heating value ranged from

1024.7 to 1053.2 Btu. The Gulf Coast gas heating values

ranged from 10224.1 to 1029.2 Btu.

5). Acceptable results were obtained from the modeling in 3)

and 4), i.e., the interpolated values are within 0.1% of the

calculated values. Comparison of the interpolated results

with the measured values also shows good agreement.

To use the interpolation tables, one only needs to supply

the gross heating value of the wet gas using API's method

and the operating pressure heating value of the gas using

API's method and the operating pressure in psia. The

appropriate function (s) to be used are located by the

operating temperature condition (deg. F). If calculation is

needed for an intermediate temperature, then linear interpolation between the values calculated for the adjacent temperatures may be used. Z and C* relations are provided for

each gas for the range of conditions needed Iby API. It is

important to note that the relationships are not valid outside the range of conditions used to develop them and therefore should not be used beyond the temperature, pressure,

and heating value conditions stated above - please do not

extrapolate.

300
The interpolation tables are as follows. Table 10, Appendix

I, gives constants for interpolating compressibility factors

for Amarillo gas between pressures at constant temperature.

Table 11, Appendix I gives constants for interpolating critical flow factors between pressures at constant temperature.

Table 12, Appendix I presents the constants for interpolating compressibility factors for the wet Gulf Coast gas and

Table 13 Appendix I gives those for critical flow factors.

CAUTION. The Investigators are not in favor of using this

method to obtain intermediate values of Z or C*. The computer programs are available for both and would be recommended for any future work. These tables should be marked

and used only for the current work.

References

1. Ellington, R. T., Starling, K. E., Hill, M. J., and

Savidge, J. L., "High Quality Compressibility Factors

Prove Accuracy of New Correlation," Presented at 65th

Annual GPA Convention, San Antonio, TX, (1986) March

10-12.

2. Starling, K. E., Savidge, J. L. , Ellington, R. T., Reid,

T., and Shankar, S. , "New Developments in the Determination of Compressibility and Supercompressibility : Status

of Natural Gas Supercompressibility Factor and Thermodynamic Properties Correlation Research," Presented at

AGA Distribution/Transmission Conference, Chicago, IL

(1986) April 28-30.

3. Ellington, R. T., Hill, M. J., and Narayanan, S.,

"Research Data From an Industrial Compressibility Factor

Instrument for Improved Correlations, International Gas

Research Conference, Toronto, CAN, (1986) Sept. 10.

4. Starling, K. E., and Kumar, K. H. , "Computer Program for

Natural Gas Supercompressibility Factor, Custody

Transfer Calculations and Process Calculations Using the

OU/GRI Correlation," 64th Annual GPA Convention, Houston, TX (1985) March 18-20.

5. Starling, K. E., et al., "Development of an Equation of

State for the Computation of Natural Gas Supercompressibility Factor and Other Properties," Operating Section

Proceedings of the American Gas Association, (1984).

6. Ellington, R. T., Hill, M. J., and Savidge, J. L.

,

301
Appendix A

Table 1 . Compressibility Factors for Amarillo Gas

at 288.71 K.

Composition: 90.66 % CH4 - 4.59 % C2H6 - 0.78 %

C3H8 - 0.14 % n-C4HlO - 0.10 %

i-C4H10 - 0.02 % n-C5H12 - 0.03 %

i-C5H12 - 0.03 % C6H14 - 3.22 % N2

- 0.42 % C02 - 0.01 % H20

A=V2/V1: 50.0271

B (Sec. Vir. Coef.): -0.1532 X 10(-3) l/psia

T(F) Pl(psia) P2(psia) P3(psia) Z 60.008 913.265 14.110 34.326 0.86695

60.008 913.325 14.076 34.291 0.86712

60.008 913.221 14.066 34.281 0.86703

60.008 913.229 14.068 34.289 0.86673

60.008 863.407 14.216 33.160 0.87395

60.008 863.406 14.215 33.158 0.87398

60.008 863.405 14.209 33.155 0.87383

60.008 813.470 14.228 31.927 0.88057

60.008 813.468 14.228 31.924 0.88074

60.008 813.464 14.222 31.919 0.88065

60.008 763.442 14.159 30.621 0.88774

60.008 763.440 14.159 30.622 0.88767

60.008 713.498 14.164 29.413 0.89463

60.008 713.492 14.162 29.410 0.89467

60.008 713.490 14.161 29.408 0.89473

60.008 663.552 14.172 28.224 0.90169

60.008 663.548 14.168 28.220 0.90172

60.008 613.641 14.228 27.098 0.90887

60.008 613.637 14.224 27.094 0.90891

60.008 613.634 14.219 27.090 0.90885

60.008 563.523 14.040 25.749 0.91593

60.008 563.525 14.044 25.752 0.91606

60.008 563.654 14.051 25.759 0.91626

60.008 513.744 14.233 24.795 0.92323

60.008 513.743 14.235 24.795 0.92339

60.008 513.741 14.232 24.792 0.92338

60.008 513.572 14.039 24.602 0.92317

60.008 463.518 13.925 23.356 0.93080

60.008 463.517 13.923 23.354 0.93081

60.008 463.512 13.920 23.352 0.93072

302
Appendix A

Table 1 (continued)

60.008 413.747 14.127 22.447 0.93801

60.008 413.746 14.125 22.444 0.93806

60.008 413.746 14.124 22.445 0.93792

60.008 363.623 13.933 21.158 0.94539

60.008 363.618 13.928 21.152 0.94551

60.008 363.612 13.927 21.151 0.94554

60.008 313.843 14.124 20.269 0.95278

60.008 313.843 14.128 20.273 0.95286

60.008 313.844 14.127 20.271 0.95298

60.008 263.735 13.949 19.032 0.96032

60.008 263.730 13.943 19.026 0.96037

60.008 263.723 13.938 19.020 0.96040

60.008 213.878 14.056 18.091 0.96779

60.008 213.873 14.055 18.089 0.96778

60.008 164.074 14.219 17.222 0.97537

60.008 164.050 14.192 17.195 0.97526

60.008 163.987 14.130 17.134 0.97515

303
Appendix A

o.ooouo0.00035-

0.00025-

0.00015-

ft nftftin- • ^

•

•

•

^ 0.00005-

G

LU

cy ft nnnnri-

• •

•

•

• ••

• • ••

•

O.

•^ -0.00005- •

•

•

•

•

•

• •

• •

• •

-0.00015-

•

• •

-0.00025-

-0.00035-

-b.oooiio- "- .

I - 100 200 300 UOO 500 600 700 600 000

PRESSURE (PS I A)

FIGURE 1. Z (PREC) VERSUS PRESSURE (PSIA) FOR

AMARILLO GAS AT 288.71 K.

304
o.ooouo

0.00035-

0.00030

0.00025-

0.00020'

0.00015-

O.OOOIO0.00005-

o

LU

q: 0.00000

Q-

•^ -0.00005-

-0.00010

-0.00015-

-0.00020

>0.00025-

-0.00030'

-0.00035-

-O.OOOUOAppendix A

^^^^^ ^^^^^rr^^ iiillJ«f* I f

•~F

100 200 900 tlOO 500 600 700 600 000

PRESSURE (PS I A)

FIGURE 2. Z (PREC) VERSUS PRESSURE (PS I A) FOR

AMARILLLO GAS AT 299.85 K.

305
Appendix A

Table 2, Compressibility Factors for Amarillo Gas

at 299.85 K.

Composition: 90.66 % CH4 - 4.59 % C2H6 - 0.78 %

C3H8 - 0.14 % n-C4H10 - 0.10 %

i-C4H10 - 0.02 % n-C5H12 - 0.03 %

i-C5H12 - 0.03 % C6H14 - 3.22 % N2

- 0.42 % C02 - 0.01 % H20

A=V2/V1: 49.9518

B (Sec. Vir. Coef.): -0.1334 X 10(-3) 1/psia

T(F) Pl(pEia) P2(psia) P3(psia) Z

80.060 913.270 14.136 33.954 0.88631

80.060 913.269 14.130 33.951 0.88616

80.060 913.269 14.134 33.951 0.88634

80.060 863.328 14.140 32.746 0.89173

80.060 863.324 14.140 32.742 0.89192

80.060 863.317 14.133 32.735 0.89192

80.060 813.452 14.231 31.630 0.89767

80.060 813.450 14.225 31.627 0.89754

80.060 813.447 14.222 31.622 0.89761

80.060 763.500 14.234 30.444 0.90339

80.060 763.500 14.235 30.444 0.90350

80.060 763.501 14.237 30.443 0.90358

80.060 713.469 14.142 29.179 0.90914

80.060 713.546 14.230 29.268 0.90903

80.060 713.546 14.233 29.268 0.90921

80.060 663.568 14.200 28.069 0.91546

80.060 663.565 14.195 28.065 0.91538

80.060 663.561 14.190 28.059 0.91539

80.060 613.628 14.211 26.933 0.92133

80.060 613.626 14.209 26.929 0.92148

80.060 613.623 14.208 26.926 0.92157

80.060 563.495 14.017 25.600 0.92779

80.060 563.493 14.017 25.598 0.92789

80.060 563.492 14.014 25.598 0.92773

80.060 563.728 14.270 25.855 0.92760

80.060 563.727 14.268 25.853 0.92758

80.060 563.719 14.260 25.845 0.92756

80.060 513.565 14.040 24.501 0.93403

80.060 513.550 14.021 24.485 0.93376

80.060 513.541 14.016 24.478 0.93399

306
Appendix A

Table 2 (continued)

80.060

80.060

80.060

80.060

80.060

80.060

80.060

80.060

80.060

80.060

80.060

80.060

80.060

80.060

80.060

80.060

80.060

80.060

80.060

80.060

80.060

80.060

463.650

463.623

463.617

463.823

413.917

413.906

413.898

363.982

363.976

363.972

314.034

314.033

314.031

264.083

264.083

264.083

213.920

213.913

213.904

164.014

163.980

163.974

4.082

4.050

4.045

4.268

4.320

4.305

4.298

4.337

4.331

4.326

4.343

4.341

4.339

4.345

4.346

4.345

4.116

4.107

4.098

4.164

4.129

4.125

23.439

23.406

23.400

23.623

22.581

22.567

22.559

21 518

21.512

21.506

20.458

20.456

20.454

19.408

19.408

19.407

18.140

18.131

18.121

17.162

17.128

17.123

0.93997

0.94007

0.94015

0.94018

0.94645

0.94638

0.94647

0.95273

0.95282

0.95291

0.95919

0.95912

0.95920

0.96549

0.96568

0.96571

0.97221

0.97211

0.97232

0.97866

0.97856

0.97866

307
Appendix B

Table 3. Compressibility Factors for Gulf Coast Gas at

288.71 K.

Composition: 96.5007 % CH4 - 1.7490 % C2H6 - 0.4003

% C3H8 - 0.0999% n-C4H10 - 0.1000 %

i-C4H10 - 0.1001 % n-C5H12 - 0.0999 %

i-C5H12 - 0.1001 % C6H14 - 0.2501 %

N2 - 0.5990 % C02

A=V2A1: 50.0221

B (Sec. Vir. Coef.)= -0.1484 X 10(-3) 1/psia

T(F) Pl(psia) P2(psia) P3(psia) Z

60.008 763.416 14.196 30.606 0.89072

60.008 763.409 14.183 30.591 0.89080

60.008 763.366 14.140 30.542 0.89111

60.008 713.719 14.442 29.642 0.89766

60.008 713.704 14.429 29.624 0.89794

60.008 713.687 14.417 29.610 0.89803

60.008 713.695 14.427 29.626 0.89769

60.008 663.742 14.427 28.436 0.90454

60.008 663.740 14.424 28.428 0.90482

60.008 663.738 14.425 28.435 0.90449

60.008 663.743 14.432 28.440 0.90457

60.008 613.791 14.428 27.263 0.91148

60.008 613.778 14.414 27.246 0.91169

60.008 613.777 14.411 27.245 0.91154

60.008 563.820 14.410 26.087 0.91855

60.008 563.822 14.414 26.089 0.91867

60.008 563.824 14.414 26.092 0.91847

60.008 563.812 14.402 26.081 0.91838

60.008 513.860 14.399 24.938 0.92541

60.008 513.858 14.397 24.932 0.92578

60.008 513.853 14.396 24.933 0.92552

60.008 513.850 14.389 24.928 0.92539

60.008 463.892 14.384 23.797 0.93258

60.008 463.888 14.379 23.790 0.93281

60.008 463.882 14.375 23.785 0.93290

60.008 463.877 14.370 23.782 0.93277

60.008 413.921 14.367 22.671 0.93978

60.008 413.920 14.365 22.668 0.93999

60.008 413.920 14.367 22.671 0.93980

60.008 413.924 14.374 22.677 0.93993

60.008 413.932 14.378 22.683 0.93972

308
Appendix B

Table 3 (continued)

60.008 363.981 14.381 21.595 0.94681

60.008 363.983 14.383 21.593 0.94716

60.008 363.987 14.385 21.597 0.94698

60.008 363.988 14.389 21.601 0.94696

60.008 314.037 14.390 20.526 0.95417

60.008 314.037 14.387 20.524 0.95411

60.008 314.030 14.378 20.514 0.95429

60.008 314.026 14.374 20.510 0.95415

60.008 264.067 14.368 19.445 0.96112

60.008 264.065 14.364 19.439 0.96154

60.008 264.061 14.361 19.436 0.96139

60.008 264.056 14.357 19.432 0.96144

60.008 214.102 14.355 18.386 0.96858

60.008 214.101 14.354 18.384 0.96867

60.008 214.101 14.351 18.383 0.96833

60.008 214.097 14.350 18.381 0.96859

60.008 164.144 14.349 17.350 0.97570

60.008 164.143 14.349 17.350 0.97573

60.008 164.144 14.349 17.350 0.97575

60.008 114.192 14.350 16.336 0.98299

60.008 114.192 14.351 16.336 0.98309

60.008 114.192 14.351 16.337 0.98301

60.008 114.194 14.353 16.339 0.98308

60.008 114.193 14.351 16.337 0.98324

60.008 114.191 14.348 16.334 0.98315

309
Appendix B

O.OOOUQ0.00035-

oon^n.

0.00025-

Qon^fl-

• •

•

•

0.00015-

OQOIQ-

• •

•

•

•

• • •

• •

^

0.00005- O

LU

Q. 0.00000-

M

-0.00005-

-0.00010-

-0.00015-

•

•

• s

•

• •

•

•

•

•• •

• •

•

•

•

•

•

• •

•

••

•

-0.00025- • •

*V. UWU3U-

-0.00035-

-0.00040-

100 200 300 UOO 500 600 700 600

PRESSURE (PS I A)

FIGURE 3. Z (PREC) VERSUS PRESSURE (PSIA) FOR

GLLF COAST GAS AT 288.71 K.

310
Appendix B

Table ^. Compressibility Factors for Gulf Coast Gas at

at 299.85 K.

Composition: 96.5007 % CH4 - 1.7490 % C2H6 - 0.4003

% C3H8 - 0.0999% n-C4H10 - 0.1000 %

i-C4HiO - 0.1001 % n-C5H12 - 0.0999 %

i-C5H12 - 0.1001 % C6H14 - 0.2501 %

N2 - 0.5990 % C02

A=V2A1: 49.9162

B (Sec. Vir. Coef.): -0.1284 X 10 (-3) 1/psia

T(F) PKpsia) P2(psia) P3(psia) Z

80.060 763.529 14.303 30.472 0.90644

80.060 763.529 14.307 30.475 0.90649

80.060 763.523 14.305 30.472 0.90650

80.060 713.566 14.293 29.291 0.91223

80.060 713.537 14.264 29.261 0.91226

80.060 713.520 14.247 29.245 0.91222

80.060 663.416 14.087 27.925 0.91818

80.060 663.414 14.084 27.923 0.91813

80.060 663.408 14.082 27.921 0.91817

80.060 613.487 14.108 26.805 0.92391

80.060 613.479 14.102 26.797 0.92402

80.060 613.474 14.097 26.790 0.92416

80.060 613.468 14.092 26.786 0.92410

80.060 563.554 14.130 25.696 0.92986

80.060 563.554 14.132 25.696 0.92997

80.060 563.541 14.116 25.683 0.92981

80.060 513.613 14.139 24.588 0.93581

80.060 513.613 14.147 24.593 0.93609

80.060 513.617 14.151 24.595 0.93619

80.060 513.612 14.143 24.589 0.93604

80.060 513.607 14.139 24.585 0.93605

80.060 463.741 14.230 23.572 0.94210

80.060 463.741 14.230 23.572 0.94212

80.060 413.745 14.178 22.432 0.94798

80.060 413.808 14.178 22.432 0.94812

80.060 413.739 14.175 22.428 0.94809

80.060 413.828 14.273 22.527 0.94796

80.060 413.809 14.231 22.485 0.94802

80.060 363.945 14.344 21.521 0.95414

80.060 363.949 14.348 21.523 0.95426

80.060 363.953 14.355 21.531 0.95412

311
Appendix B

Table 4 (continued)

80.060

80.060

80.060

80.060

313.939

313.945

313.949

313.978

14.288

14.296

14.302

14.330

20.399

20.407

20.413

20.443

0.96038

0.96055

0.96053

0.96026

80.060

80.060

80.060

263.935

263.930

263.932

14.231

14.230

14.233

19.291

19.290

19.293

0.96689

0.96681

0.96689

80.060

80.060

80.060

213.995

213.992

213.988

14.244

14.239

14.236

18.266

18.261

18.259

0.97304

0.97309

0.97303

80.060

80.060

80.060

164.035

164.034

164.040

14.237

14.241

14.252

17.234

17.23 9

17.250

0.97930

0.97923

0.97937

312
Appendix B

Q.OOOUO0.00035-

noQ^n0.00025-

f\ nnn^fi0.00015- •

• •

QQQ1Q- •

• • Q 0.00005-

^- fl nnnnn. • •

•

•

•

t

• 1

• s

-0.00005- •

1

• •

•

•

••

•

•

•

•

•

• •

s

•

_fi nfMiiH- ^

-0.00015- • •

_n nnn^n. •

-0.00025- •

-0.00035-

-O.QOOilO1 1 1h""^ h"^

100 200 300 <100 500 600 700 800

PRESSURE (PS I A)

FIGURE k I (PREC) VERSUS PRESSURE (PS I A) FOR

GULF COAST GAS AT 299.85 K.

313
Appendix C

Comparison of Calculated and Experimental

Compressibility Factors, Z, - Wet Amarillo Gas

314
Table 5 Comparison of Calculated and Experimental

Compressibility Factors, Z. - Wet Amarillo Gas

Temperature Pre ssnre Z- factor Z-f actor Pe r c ent

F ps ia exp. cal c . deviation

SB=:s = ss = = = = = :===============:============ =========== 60.008 163 .987 0.97515 0.97542 -0.027

60.008 164.050 0.97526 0.97541 -0.015

60.008 164.075 0.97537 0.97540 -0.004

60.008 213 .874 0.96778 0.967 96 -0.019

60.008 213 .879 0.96779 0.967 96 -0.018

60.008 263.724 0.96040 0.96053 -0.014

60.008 263 .731 0.96037 0.96053 -0.017

60.008 263.736 0.96032 0.96053 -0.022

60.008 313.844 0.95278 0.95308 -0.031

60.008 313 .844 0.95286 0.95308 -0.023

60.008 313 .845 0.95298 0.95308. -0.010

60.008 363.613 0.94554 0.94570 -0.017

60.008 363.619 0.94551 0.94570 -0.020

60.008 363.624 0.94539 0.94570 -0.033

60.008 413 .747 0.93806 0.93830 -0.026

60.008 413 .747 0.937 92 0.93830 -0.041

60.008 413 .748 0.93801 0.93830 -0 .031

60.008 463.513 0.93072 0.93100 -0 .030

60.008 463 .518 0.93081 0.93099 -0 .020

60.008 463 .519 0.93080 0.93099 -0 .021

60.008 513 .574 0.92317 0.92368 -0.056

60.008 513 .743 0.92338 0.92366 -0 .030

60.008 513 .745 0.92339 0.92366 -0.029

60.008 513 .746 0.92323 0.92366 -0.046

60.008 563 .525 0.91593 0.91643 -0.055

60.008 563 .527 0.91606 0.91643 -0.041

60.008 563.656 0.91626 0.91641 -0.017

60.008 613 .636 0.90885 0.90921 -0.040

60.008 613 .639 0.90891 0.90921 -0.033

60.008 613 .643 0.90887 0.90921 -0.038

60.008 663 .550 0.90172 0.90208 -0 .040

60.008 663.554 0.90169 0.90208 -0.043

315
Table 5

60.008

60.008

60.008

713 .492

713.494

713 .500

0.89473

0.89467

.89463

0.89501

0.89501

0.89501

-0.032

-0.038

-0.043

60.008

60.008

763.443

763.445

0.88767

0.88774

0.88802

0.88802

-0.03 9

-0.032

60.008

60.008

60.008

813 .467

813 .471

813 .473

0.88065

0.88074

0.88057

0.88110

0.88110

0.88110

-0.051

-0.041

-0 .060

60.008

60.008

60.008

863 .408

863.409

863 .410

0.87383

0.87398

0.87395

0.87428

0.87428

0.87428

-0.052

-0.035

-0.038

60.008

60.008

60.008

60.008

913 .224

913 .232

913.268

913 .328

0.86703

0.86673

0.86695

0.86712

0.86758

0.86758

0.86758

0.867 57

-0.064

-0.098

-0.072

-0.052

80.060

80.060

80.060

163.974

163.981

164.014

0.97866

0.97856

0.97866

0.97859

0.97859

0.97859

0.007

-0.003

0.007

80 .060

80.060

80.060

213 .905

213 .914

213 .921

0.97232

0.97211

0.97221

0.97213

0.97212

0.97212

0.020

-0.002

0.009

80.060

80.060

80.060

264.084

264.084

264.084

0.96549

0.96568

0.96571

0.96566

0.96566

0.96566

-0.017

0.002

0.006

80 .060

80 .060

80.060

314.032

314.034

314.035

0.95920

0.95912

0.95919

0.95925

0.95925

0.95925

-0.005

-0 .013

-0.006

80.060

80.060

80.060

363.973

363.977

363.983

0.95291

0.95282

0.95273

0.95288

0.95288

0.95288

0.003

-0.006

-0.015

80.060

80.060

80 .060

413 .899

413.907

413 .918

0.94647

0.94638

0.94645

0.94655

0.94655

0.94655

-0.008

-0.018

-0.010

80.060

80.060

80.060

80.060

463 .619

463.624

463.651

463.824

0.94015

0.94007

0.93997

0.94018

0.94029

0.94029

0.94029

0.94027

-0.015

-0.024

-0.034

-0.009

80.060

80.060

80.060

513.543

513 .551

513 .566

0.93399

0.93376

0.93403

0.93406

0.93406

0.93406

-0.007

-0.032

-0.003

316
Table 5

80.060 563.494 0.92773 0.92788 -0.016

80.060 563.495 0.92789 0.92788 0.001

80.060 563 .497 0.9277 9 0.92788 -0.009

80.060 563.721 0.92756 0.92785 -0.031

80.060 563.729 0.92758 0.92785 -0.029

80 .060 563.730 0.92760 0.92785 -0.027

80.060 613 .625 0.92157 0.92173 -0.018

80 .060 613 .628 0.92148 0.92173 -0.027

80.060 613.630 0.92133 0.92173 -0.044

80.060 663.563 0.91539 0.91568 -0.031

80.060 663 .567 0.91538 0.91568 -0.032

80.060 663.570 0.91546 0.91568 -0.024

80.060 713 .471 0.90914 0.90970 -0.061

80.060 713 .548 0.90903 0.90969 -0.072

80.060 713 .548 0.90921 0.90969 -0.052

80.060 763.502 0.90339 0.9037 8 -0.043

80.060 763.502 0.90350 0.90378 -0.031

80.060 763.504 0.90358 0.9037 8 -0.022

80 .060 813 .450 .89761 0.89795 -0.038

80 .060 813 .453 0.89754 0.89795 -0.046

80.060 813 .455 0.89767 0.89795 -0.031

80.060 863 .320 0.8 9192 0.89222 -0.034

80.060 863 .327 0.8 9192 0.89222 -0.034

80.060 863 .331 0.89173 0.89222 -0.055

80.060 913 .272 0.88616 0.88659 -0.048

80 .060 913 .272 0.88634 0.88659 -0.028

80.060 913 .273 0.88631 0.88659 -0.031

317
Appendix D

Table 6

Comparison of Calculated and Experimental

Compressibility Factors, Z, - Dry Gulf Coast Gas

Temperature Pre ssure Z-f actor Z- factor Percent

F ps ia exp. calc . deviation

asBssBBsssssas bbsbbs= sbs:sb:sb = = = c = = = sb:= = s=s = = =: = = = 60.008 114.191 0.98315 0.98336 -0.021

60.008 114.192 0.98299 0.98336 -0.037

60.008 114.192 0.98309 0.98336 -0.027

60.008 114.192 0.98301 0.98336 -0.035

60.008 114.193 0.98324 0.98336 -0.012

60.008 114.194 0.98308 0.98336 -0.028

60.008 164.144 0.97573 0.97609 -0.037

60.008 164.144 0.97570 0.97609 -0.040

60.008 164.144 0.97575 0.97609 -0.035

60.008 214.098 0.96859 0.96884 -0 .026

60.008 214.102 0.96867 0.96884 -0.018

214.102 0.96833 0.96884 -0.053

60.008 214.103 0.96858 0.96884 -0 .027

60.008 264.057 0.96144 0.96161 -0.018

60.008 264.062 0.96139 0.96161 -0.023

60.008 264.066 0.96154 0.96161 -0.007

60.008 264.068 0.96112 0.96161 -0.051

60.008 314.027 0.95415 0.95440 -0,026

60.008 314.031 0.95429 0.95440 -0 .011

60.008 314.038 .95417 0.95440 -0 .024

60.008 314.038 0.95411 0.95440 -0.030

60.008 363.982 0.94681 0.94721 -0.043

60.008 363.984 0.94716 0.94721 -0.006

60.008 363.988 0.94698 0.94721 -0.025

60.008 363.989 0.94696 0.94721 -0.027

60.008 413 .921 0.93999 0.94006 -0.008

60.008 413 .921 0.93980 .94006 -0.028

60.008 413 .922 0.93978 0.94006 -0.030

60.008 413.925 0.93993 0.94006 -0.014

60.008 413.933 0.93972 0.94006 -0.036

60.008 463.878 0.93277 0.93294 -0.019

60.008 463.883 0.93290 0.93294 -0.005

60.008 463 .890 0.93281 0.93294 -0.014

60.008 463.893 0.93258 0.93294 -0.039

60.008 513.852 0.92539 0.92586 -0.051

60.008 513.855 0.92552 0.92586 -0.037

60.008 513 .859 0.92578 0.92586 -0.009

60.008 513 .862 0.92541 0.92586 -0.049

318
Appendix D

60.008

60.008

60.008

60.008

S63.814

563.822

563.824

563.826

0.91838

0.91855

0.91867

0.91847

0.91883

0.91883

0.91883

0.91883

-0.049

-0.030

-0.017

-0.03 9

60.008

60.008

60.008

613 .779

613 .780

613 .793

0.91154

0.91169

0.91148

0.91185

0.91185

0.91185

-0.034

-0.017

-0.040

60.008

60.008

60.008

60.008

663.740

663.742

663.744

663.745

0.90449

0.90482

0.90454

0.90457

0.90493

0.90493

0.90493

0.90493

-0.048

-0.012

-0.043

-0.039

60.008

60.008

60.008

60.008

713 .689

713 .697

713.706

713.721

0.89803

0.89769

0.89794

0.89766

0.89807

0.89807

0.89807

0.89807

-0.005

-0.042

-0.014

-0.045

60.008

60.008

60.008

763.368

763.411

763.419

0,89111

0.89080

0.89072

0.89132

0.89132

0.89132

-0.024

-0.058

-0.067

80.060

80 .060

80.060

164.034

164.035

164.040

0.97923

0.97930

0.97 937

0.97919

0.97919

0.97919

0.004

0.011

0.018

80 .060

80.060

80.060

213.989

213 .993

213 .996

0.97303

0.97309

0.97304

0.97291

0.97291

0.97291

0.012

0.019

0.013

80.060

80.060

80 .060

263.931

263.933

263.936

0.96681

0.96689

0.96689

0.96666

0.96666

0.96666

0.016

0.024

0.024

80.060

80.060

80.060

80.060

313 .940

313 .946

313 .950

313 .979

0.96038

0.96055

0.96053

0.96026

0.96043

0.96043

0.96043

0.96042

-0.005

0.013

0.011

-0.017

80.060

80.060

80 .060

363.946

363 .950

363.954

0.95414

0.95426

0.95412

0.95423

0.95423

0.95423

-0.010

0.003

-0.012

80.060

80.060

80.060

80.060

80.060

413.740

413 .746

413 .809

413.810

413 .829

0.94809

0.94798

0.94812

0.94802

0.94796

0.94811

0.94811

0.94810

0.94810

0.94810

-0.002

-0.014

0.002

-0.009

-0.015

80.060

80.060

463.742

463.742

0.94210

0.94212

0.94200

0.94200

0.010

0.012

80 .060

80.060

80.060

80.060

80 .060

513 .609

513 .613

513 .615

513.615

513 .619

0.93605

0.93604

0.93581

0.93609

0.93619

319

0.93596

0.93596

0.93596

0.93596

0.93596

0.009

0.008

-0.016

0.014

0.024
Appendix D

80.060 563.543 0.92981 0.92997 -0.017

80.060 563.556 0.92986 0.92996 -0.011

80.060 563.556 0.92997 0.92996 0.001

80.060 613.470 0.92410 0.92403 0.008

80.060 613.476 0.92416 0.92403 0.014

80.060 613.481 0.92402 0.92403 -0.001

80.060 613.489 0.92391 0.92403 -0.013

80.060 663.410 0.91817 0.91815 0.002

80.060 663.416 0.91813 0.91815 -0.003

80.060 663.418 0.91818 0.91815 0.003

80.060 713.522 0.91222 0.91233 -0.012

80.060 713.539 0.91226 0.91232 -0.007

80.060 713.568 0.91223 0.91232 -0.010

80.060 763.525 0.90650 0.90659 -0.010

80.060 763.531 0.90644 0.90659 -0.016

80.060 763.531 0.90649 0.90659 -0.011

I

(

320
Appendix G

Figure 5

PRESSURE - TEMPERATURE DIAGRAM

AMARILLO NATURAL GAS

on

1100^

1000-

900-^

800-

700-:

600J

m 500-

Q.

400-:

300^

200-

100^

BUBBLE

POINT

LOCUS

DEW POINT LOCUS

a b c d e f

a b c d e f

a b c d e f

a b c d e (

Oq—II M 1 1 1 > 1 1 1

I 1 I I ' ' I I I 1 1 n n I M I

1 1

1 I I n 1

1 1 1 1 I 1 1 1 1 [1 1 1 1 1 Ti 1 "ij >

• f 1

'

-160 -120 -80 -40 40 80

TEMPERATURE. DEGREE F.

321
Appendix H

Figure 6

PRESSURE - TEMPERATURE DIAGRAM

GULF COAST NATURAL GAS

1200-

1100 -^

1000-^

900-

800-^

700 -E

j^ 600

oo 500

UJ

a.

400 -i

300 -E

200 -=

100 -^

•=]

BUBBLE

POINT

LOCUS

DEW POINT LOCUS

a b c d e f

b c d e f

a b c d e f

a b c d e f

a b c d e f

I

' Mlli I I ||l UN

-300 -250

I I 1 1

1

I'l l III 1 1

1

1 1

1

1 1

1

M

I

' ' I

T

I

n

> » 1 1 1

1

1 M » 1 M H n 1 1

1

1

1

j 1 1

1

1 n 1 1 n

-200 -150 -100 -50 -50 100

TEMPERATURE, DEGREE F.

322
Appendix E

Database Structure

Several databases were needed to store the test run data. The following

tables give the structures of these. Each record of a database con- tained a maximum of 32 fields. Due to the number of individual data

items necessary for each test run or group of test runs, several

databases were used to record the data. The following gives a short

description of each type of database and a listing of its structure.

Structural information is composed of a field name and type, an indicator of either numeric (N) or character (C) type, and the width of

the field given in the number of characters in the field. For numeric

fields a decimal point position is included.

Each day's data was contained in a set of databases. The file names of

the database set of a day always contained the year and day of the date

of the test run. For example for test run data taken on July 30, 1985,

each of the following file names were used for the database set.

0730HEAD Header file This file contained one record per test

run.

0730PRES Pressure file This file contained one record for each set

of observations taken by the datalogger.

One set was taken approxi-mately every 2 seconds

.

0730DELP

0730STAT

0730COEF

Differential

Pressure

Calibration

file

Static

Pressure

Calibration

file

Pressure

Transducer

Calibration

Coefficients

This file contained the response values

for the differential pressure transducers

and standard. One record for each

calibration point.

This file contained the response values

for the static pressure transducers

and weight designation of the deadweight

tester. One record for each calibration

point.

This file contained the response model

coefficients for each transducer. One

record per transducer.

Field names were selected to be descriptive of the parameter stored in

each field, e.g., the field NOZZLrl in the header database is a character string with the nozzle designation. If only one nozzle were in

operation in the test run then OFF was stored in the appropriate fields.

These databases were used to maintain the complete database for the data

acquisition and analysis procedures. It does not reflect the structure

or ordering of the archival database which is given in another appendix

to this report.

323
Header Database Structure

FLD NAME TYPE WIDTH DEC

001 RUN : NUMBER N 004

002 NUM:PR:REC N 004

003 DATE C 008

004 TIME C 008

005 N0ZZL:1 c 020

006 N0ZZL:2 c 020

007 N0ZZL:3 c 020

008 N0ZZL:4 c 020

009 METR:TUBE c 020

010 ORF: PLATE c 020

Oil P:BARO c 012

012 TRO : ZERO N 012 010

013 TRl : ZERO N 012 010

014 TR2 : ZERO N 012 010

015 TR3 : ZERO N 012 010 ** TOTAL ** 00205

Chromato graph Database Structure

STRUCTURE FOR FILE: D: 0730NCAL.DBF

NUMBER OF RECORDS: 00009

FLD NAME TYPE WIDTH DEC

001 DATE C 008

002 RUN : TIME C 008

003 ANL:TIME C 008

004 MODE C 004

005 ALARM C 020

006 C6 : PLUS C 020

007 NITROGEN C 020

008 METHANE C 020

009 C02 C 020

010 ETHANE C 020

Oil PROPANE C 020

012 I : BUTANE C 020

013 N : BUTANE C 020

014 I : PENTANE C 020

015 N : PENTANE C 020 ** TOTAL ** 00249

324
Pressure Database Structure

STRUCTURE FOR FILE: D:0730PRES.DBF

NUMBER OF RECORDS: 01200

FLD NAME TYPE WIDTH DE

001 RUN : NUMBER N 004

002 DATE C 008

003 TIME C 008

004 CHO : PRES C 012

005 CHI : PRES C 012

006 CH2 : PRES C 012

007 CH3 : PRES C 012

008 CH4 : PRES C 012

009 CH5 : PRES C 012

010 CH6 : PRES C 012

Oil CH7 : PRES C 012

012 CH8 : PRES C 012

013 CH9 : PRES C 012

014 CH10:PRES C 012

015 CHI 1: PRES C 012

016 CH12:PRES C 012

017 PRTl : FOR C 012

018 PRT2 : FOR C 012

019 PRT3 : FOR C 012

020 PRT4 : FOR C 012

021 PRT5 : FOR c 012

022 PRTl: REV c 012

023 PRT2:REV c 012

024 PRT3:REV c 012

025 PRT4 : REV c 012

026 PRT5 : REV c 012

027 PRTCKFOR c 012

028 PRTCKREV c 012 ** TOTAL ** 00321

Differential Pressure Calibration Database Structure

STRUCTURE FOR FILE: D: 0730DELP. DBF

DEC

NUMBER OF RECORDS: 00105

FLD NAME TYPE WIDTH

001 RUN : NUMBER N 004

002 DATE C 008

003 TIME C 008

004 DDR: ZERO C 012

005 DDR : PRES C 012

006 SER:NUM1 C 012

007 VOLTAGEl C 012

008 SER:NUM2 C 012

009 V0LTAGE2 C 012 ** TOTAL ** 00093

325
Static Pressure Calibration Database Structure

STRUCTURE FOR FILE: D: 0730STAT.DBF

NUMBER OF RECORDS: 00008

FLD NAME TYPE WIDTH DEi

001 RUN : NUMBER N 004

002 DATE C 008

003 TIME C 008

004 ATM:PRES c 012

005 DWT:SER:N c 012

006 DWT : TEMP c 012

007 DWT:CAR:WT c 012

008 DWT:T0T:WT c 012

009 DWT : ST : PRS c 012

010 SER:NUM1 c 012

Oil VOLTAGEl c 012

012 SER:NUM2 c 012

013 V0LTAGE2 c 012

014 SER:NUM3 c 012

015 V0LTAGE3 c 012

016 SER:NUM4 c 012

017 V0LTAGE4 c 012

018 SER:NUM5 c 012

019 VOLTAGES c 012

020 P:BAR0 c 012 ** TOTAL ** 00225

Pressure Transducer Response Model Coefficient Database Structure

STRUCTURE FOR FILE: D: 0730COEF.DBF

NUMBER (OF RECORDS: 00018

DATE OF LAST UPDATE: 07/06/88

PRIMARY USE DATABASE

FLD NAME TYPE WIDTH DE< 001 SER:NUM C 012

002 DATE C 008

003 TIME C 008

004 C0EF:C0NS C 012

005 C0EF:LIN C 012

006 C0EF:QUAD C 012

007 COEF:CUB C 012

008 STD : DEV C 012

009 CAL:PRES N 012 oo: ** TOTAL ** 00101

326
APPENDIX F

Report of Calibration of the 0.125-inch Diameter Nozzle

The report of calibration reproduced here was performed by Colorado

Engineering Experiment Station for one of the nozzles used in the

testing program. It is reproduced here in keeping with the intent of

NBS and API to document this orifice test program as completely as practicable. No alterations have been made to the report with the

exception of placing page numbers on each page to conform with the page

number system of this report.

327
LABORATORY/OFFICE

54043 Couniy Rd 37

P Box 41 Nunn. Colo 80648

303-897-271

1

COLORADO ENGINEERING

EXPERIMENT STATION INC,

November 24, 1986

Mr. VJayne Fling, Jr.

OXY Oil & Gas Corp.

Post Office Box 300

Tulsa, OK 74102

Dear Wayne:

Enclosed is the calibration information on the second (latest

manufacture) 1/8 inch NGPL critical flow venturi.

The following information was given by telephone to Charlie Sindt

on September 18, 1984:

Throat Diameter: 0.125 inches

A Coefficient: 0.982698

B Coefficient: 8.29

All my calibration reports show a throat diameter of 0.125 inches

and I have no idea where the diameter in the NBS report (0.1248

inches) came from. These three numbers listed above must be used

together to provide a complete, accurate use of the calibration.

If I can be of further help please let me know.

Yours truly.

Walt Seidl

enc

CO Dr. James Whetstone, NBS

Mr. Charles Sindt, NBS

328
LABORATORY/OFFICE:

54043 County Rd. 37 P.O Box 41 Nunn. Colo. 80648

303-897-2711

COLORADO ENGINEERING

EXPERIMENT STATION INC

CALIEIRATI0N 0F A S^NIC Ni322LE

THR0AT .125 INCHES (N0riIHAL)

F0R: NBS 0RDER: VERBAL C. SIHDT

DATA FILE: 84NBS39 DATE: 17 AUG 1984

INLET DIA: 1.66 INCHES THROAT DIA: 0.125 INCHES

TEST GAS: AIR STD DENSITY= 0.074916 LBM/CU-FT

AT STANDARD C0NDITI0NS 0F 529.69 DEO R, AND 14.696 PSIA

K FACT0R: DISCHARGE C0EFFICIENT

PSIA: INLET STATIC PRESSURE IN PSIA

DEG R: INLET TEMPERATURE IN DEGREES RANKINE

REY N0: THR0AT REYN0LDS NUMBER

L PSIA DEG R K FACT0R REY N0 LBM/SEC

1 905.75 537 0.98792 2554700. 0.25816

2 855.96 534.1 0.98793 2429000. 0.24444

3 806.1 534.1 0.98848 2285800. 0.23002

4 756.62 533.5 0.98861 2M6200. 0.21579

5 715.38 532.9 0.98848 2029700. 0.2039

6 657.06 530.7 0.9887 1872100. 0.18747

7

/ 607.33 531 0.98871 1726800. 0.17299

8 508.19 528.9 0.98885 1448700. 0.14469

9 408.97 531.3 0.98931 1156200. 0.11588

10 310.2 529 0.98987 880040. 0.087907

11 115.66 531 0.99065 324980. 0.032557

12 166.5 532.1 0.9922 467980. 0. 046959

13 214.31 535.4 0.99252 598560. 0. 060348

14 263.43 533.2 0.99072 739360. 0. 074307

15 361.9 533.3 0.98905 10165UO. 0.10218

AVERAGE VALUES F0R AB0VE RESULTS:

P= 510.22 PSIA liE(NSrT7= 2.6102 LBH/OUH-T

T= 532.49 DEG R VISCi)S:[TY^= 1.0227E-6 LBrt/INCH-SEC

2= 0.99162 C0MPRESSIBILITY FACT0R

C* CRIT= 0.53937 LBM-{DEG R )^0 .S/LD-SEC

329
LABORATORY/OFFICE:

54043 County Rd. 37 P Box 41 Nunn Colo 80648

303-897-271

1

COLORADO ENGINEERING

EXPERIMENT STATION INC.

CALIBRATION 0F A S0iNIC FL0U NOZZLE

THRflAT: .125 INCHES (Ni3MiNAL)

F0R: N.B.S. 0RDER: VERBAL C. SINDT

DATA FILE: 84NBS37 DATE: 16 AUGUST 1794

INLET niA: 1.66 INCHES THRfcJAT DIA: 0.125 INCHES

TEST OAS: AIR STD DENSITY= 0.074916 LBM/CU-F

T

AT STANDARD C0NDITI0NS 0F 529.69 DEO R, AND H.6V6 fSTA

K FACT0R: DISCHARGE C0EFFICIENT

PSIA: INLET STATIC PRESSURE TN PSTA

DEG R: INLET TEMPERATURE IN DEGREES RANKINE

REY N0: THR0AT REYNOLDS NUMBER

L PSIA DEC R

1 905.76 534.7

2 855.97 532.7

3 806.11 531.7

4 756.63 531.5

5 715.39 530.5

6 657.08 529

7 607.35 529.1

8 558.02 530.7

9 508.21 528.6

10 458.56 527.8

11 408.98 527.6

12 359.41 527.2

13 310.22 527.8

14 260.11 527.5

15 210.58 525.2

iVER AGE VALUES F0R

= 558.56 PSIA

K FACTOR

0.98695

0.98794

0.98793

0.98821

0.98864

0.98861

0.9893

0.98934

0.98943

0.98957

0.99004

0.98962

0.98962

0.99058

0.99225

REY N0

2567200.

2437700.

2293500.

2156200.

2042500,

1880100.

1736100.

1586600.

1450700.

1309900.

1167800.

1025400.

882470.

740130.

602770.

LBrt/SEC

0.25857

0.24482

0.23O5

0.21617

0.20447

0.1878

0.17344

0.15888

0.14483

0.13062

0.11641

0.10216

0.087996

0.073769

0.059876

DENSrT^= 2.8732 LBM/CU-F7

T= 529.43 DEG R VISC0SITY= 1.0181E-6 LBM/INCH-SEC

Z= 0.99035 C0hPRESSIBILITY FACT0R

C* CRIT= 0.54025 LBM-<DEG R)'t0.5/LB-SEC

330
COLORADO ENGINEERING

'imTomXT EXPERIMENT STATION INC,

PO Box 41 Nunn. Colo 80648

303-897-2711

84A15 ^6 AUGUST 1984 NBS N«Z2LE .125 THRiAT

I TCAL2 TCAL4 TCAL5 AVG T PCAL MASS %DEV

1 XXXXX 72.88 73.01 72.94 1<S32.57 2542.3 -0.001

2 XXXXX 72.87 73 72.93 1632. 5<S 2542.33 0.001

MHAVE)= 2542.32 H1(C0RR)= 2545.28

I TCAL2 TCAL4 TCAL5 AUG T PCAL MASS ZDEV

1 XXXXX 71.55 71.76 71.65 823.893 1290.31 -0.O01

2 XXXXX 71.55 71.77 71.66 823.934 1290.35 0.001

M2(AVE)= 1290.33 M2(C0RR)= 1291.87

TIMERS: 1 = 6132.03 2 = 6132.11 3 = 6132. 4 = 6132.

TIME: 6132.04 SEC0NDS MASS FL»U RATE: 0.204403 P0UNDS/SEC0ND

BAR0METRIC PRESSURE: 12.17 PSIA

N0ZZLE: 0.125 THR0AT DIAMETER: 0.125 INCHES

P START= 703.395 P ST0P= 703.395

P MIN= 703.395 P MAX:= 703.395 P ME= 703.395 715.565 PSIA

T START= 74.4 T ST0P= 70.3

T MIN= 70.3 T MAX= 74.4 T AV£= 71.5717 DEG F 531.262 DEG R

MASS FL0U RATE: 0.20433 P0UNDS PER SECOND

Z= 0.9882 V0= 1.02E-6 C0= 0.5426 R= 2039520. C= 0.98854

331
COLORADO ENGINEERING

LABORATORY/OFFICE -r- vr»T- t. t» * t- -KTrr. r>r^ . r^^ ^

54043 CounlyRd. 37 EXPERIMENT STATION INC,

P.O Box 41 Nunn, Colo 80648

303-897-2711

BAA] 6 NBS N0Z2LE 17 AUG 1<?84 .125 THR0AT

I TCAL2 TCAL4 TCALS AW T PCAL MASS 7.1il^

1 XXXXX 75.41 75.69 75.55 1579.19 2445.93

2 XXXXX 75.3 75.57 75.44 1578.81 2445.95

H1(AVE)= 2445.94 M1(C0RR)= 244B.81

I 7CAL2 TCAL4 TCAL5 AUG T PCAL HASS 2DEV

1 XXXXX 74.41 74.79 74.6 791.936 1232.25 0.O06

2 XXXXX 74.42 74.78 74.6 791.847 1232.11 -0.006

M2(AVE)= 1232.18 H2(C0RR)= 1233.57

TIMERS: 1 = 5962.92 2 = 5962.97 3 = 5962.87 4 = 5962.86

TIME: 5962.91 SEC0NDS MASS FUJU RATE: 0.203799 P0UNDG/SEC0ND

BAR0METRIC PRESSURE: 12.157 P81A

N0ZZLE: 0.125 THR0AT DIAMETER: 0.125 INCHES

P START= 703.395 P ST0P= 703.395

P MIN= 703.395 P MAX= 703.395 P AVE= 703.395 715.552 PSIA

T START= 76.7 T ST0P= 72.5

T MIN= 72.5 T MAX= 76.7 T A'JE= 74.2646 DEC F 533.955 DEC R

MASS FL0U RATE: 0.203722 P0UNDS PER 8ECi)ND

Z= 0.9887 V0= 1.024E-6 C0= 0.5425 R= 2025570. C= 0.98848

332
Le«dsl-squcire5 fit of equdtiun of tlie for« C ~ A + B/sqrCR)

where C is the discharge coefficient and R ;is the R«ynald<i nuMber

DATA FILE: 2RNBS

Nurtber of data points: 12

C= 0.982698 + 8.29 /..qi-(R)

F'erceivt Standard Devivitiou: 0.02070S3

Rey No Cd Cd(calc) X Dev

1 1.7268 E+6 0.98872 0.90901 -0.029

2 1.7361 E+6 0.98930 0.98899 0.031

3 1.3721 E+6 0.98871 0.98876 -0.005

4 1.8801 E+6 0.98862 0.98874 -0.013

J 2.0297 E+6 0.98843 0.98852 -0.004

6 2.0425 E+6 0.98864 0.98850 0.014

7 2.1462 E+6 0.98861 0.98836 0.026

8 2.1562 E+6 0.98821 0.98834 -0.014

9 2.2858 E+6 0.98849 0.98818 0.031

10 2.2985 E + 6 0.98793 0.98817 -0.024

11 2.4290 E+6 0.98794 0.98802 -0.008

12 2.4377 E + 6 0.98794 0.98801 -0.007

333
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Appendix G

Archival Database Structure and Format

The raw data was stored on magnetic tape to provide an archival record.

The files on the tape are arranged in the following order.

1. A copy of this document giving the structure of the tape. This

file is reproduced in ASCII form.

2. A copy of the test run inventory given in table 27 of this

report, also reproduced in ASCII form.

3. The data collected. Certain of the data files contain

coefficients for the pressure transducers.

Generally the database is arranged with the pressure transducer response

coefficients as the first file. It is followed by a file containing the

PRT coefficients. These are followed by four files containing the test run data for all runs taken on each meter tube in the order FE-7ABC, PE8ABC, FE-9ABC, and FE-OABC. These files are followed by several

auxiliary files as described below.

Database Record Structures

1. Pressure transducer calibration coefficient data blocks.

The coefficient data necessary to convert the recorded pressure

transducer readings to pressure units are recorded in a series of 13

record pairs. The format of each record pair is given here:

Record # or description

Columns Format Comments

record I

transducer serial 1

- 6 XXXXXX

number 7

- 13 blank

recording date 14 - 21 MM/DD/YY

22 blank

recording time 23 - 30 HH:MM:SS

31 - 80 blank

record II

constant term 1-16

linear term 17 - 32

quadratic term 33 - 48

cubic term 49 - 64

residual standard 65 - 80

deviation of the

fit

+N . NNNNNNNNNE+NN

+N.NNNNNNNNNE+NN

+N. NNNNNNNNNE+NN

+N . NNNNNNNNNE+NN

+N . NNNNNNNNNE+NN

335
2. Platinum resistance thermometer calibration coefficient data blocks.

The coefficient data necessary to convert the recorded voltage readings

into temperature units are recorded as a series of five records, ordered

as follows:

i) Orifice thermometer

ii) Nozzle 1 thermometer

iii) Nozzle 2 thermometer

iv) Nozzle 3 thermometer

v) Nozzle 4 thermometer

The format of the records is given here

:

Record # or descriptionColumns Format Comments

record I

PRT ID/Location 1

- 11 xxxxxxxxxxx

12 blank

Constant 13 - 19 +NNN.NN

coefficient 20 blank

Linear coefficient 21 - 27 +NNN . NN

336
3. Test run header data block.

The header data or those data occurring once in a test run are recorded

in a record pair. The format of the records is given here:

Record # or descriptionColumns Format Comments

record I

run number

number of pressure

records

date

time

nozzle 1 diameter

(in.)

nozzle 2 diameter

(in.)

nozzle 3 diameter

(in.)

nozzle 4 diameter

(in.)

156

10

11

19

20

28

29

35

36

42

43

49

50

56

18

27

34

41

48

55

80

NNNN_

blank

NNNN

blank

MM/DD/YY

blank

HH:MM:SS

blank

N . NNNN

blank

N.NNNN

blank

N.NNNN

blank

N . NNNN

blank

If any nozzle field

contains

0.0000, then the

nozzle was not in operation

in the test run.

record II

plate

identification

1 - 9 xxxxxxxxx

10 blank

plate diameter 11 - 16 N.NNNN

(in.)

17 blank

tube identification 18 - 24 XXXXXXX

25 blank

tube diameter (in.) 26 - 32 NN.NNNN

33 blank

barometric pressure 34 - 38 NN.NN

(psia)

39 - 80 blank

337
4. Pressure and temperature raw data blocks.

The pressure and temperature data are recorded in 5 record blocks. The

number of sets is given in the header block as the number of pressure

records. The format of the record sets is as follows:

Record # or descriptionColumns Format Comments

record I

run number

date

time

CHO pressure

transducer

reading (volts)

1

- 4 NNNN

5 blank

6

- 13 MM/DD/YY

14 blank

15 - 22 HH:MM:SS

23 blank

24 - 35 +N . NNNNNE+NN

36 - 80 blank

record II

CHI pressure

transducer

reading (volts)

CH2 pressure

transducer

reading (volts)

CH3 pressure

transducer

reading (volts)

CH4 pressure

transducer

reading (volts)

CHS pressure

transducer

reading (volts)

CH6 pressure

transducer

reading (volts)

1-12 +N. NNNNNE+NN

13-24 +N. NNNNNE+NN

25 - 36 +N. NNNNNE+NN

37-48 +N. NNNNNE+NN

49 - 60 +N. NNNNNE+NN

61 - 72 +N. NNNNNE+NN

73 - 80 blank

338
Record # or description

Columns Format Comments

record III

CH7 pressure

transducer

reading (volts)

CHS pressure

transducer

reading (volts)

CH9 pressure

transducer

reading (volts)

CHIO pressure

transducer

reading (volts)

CHll pressure

transducer

reading (volts)

CH12 pressure

transducer

reading (volts)

1-12 +N.NNNNNE+NN

13-24 +N.NNNNNE+NN

25-36 +N.NNNNNE+NN

37-48 +N.NNNNNE+NN

49 - 60 +N.NNNNNE+NN

61-72 +N.NNNNNE+NN

73 - 80 blank

record IV

PRTl forward

temperature

reading (volts)

PRT2 forward

temperature

reading (volts)

PRT3 forward

temperature

reading (volts)

PRT4 forward

temperature

reading (volts)

PRT5 forward

temperature

reading (volts)

PRTl reverse temperature

reading (volts)

1-12 +N.NNNNNE+NN

13-24 +N.NNNNNE+NN

25-36 +N.NNNNNE+NN

37-48 +N.NNNNNE+NN

49 - 60 +N.NNNNNE+NN

61-72 +N.NNNNNE+NN

73-80 blank

record V

PRT2 reverse temperature

reading (volts)

1-12 +N.NNNNNE+NN

339
PRT3 reverse

temperature

reading (volts)

PRT4 reverse

temperature

reading (volts)

PRT5 reverse temperature

reading (volts)

check resistor

forward voltage

check resistor

reverse voltage

13-24 +N.NNNNNE+NN

25 - 36 +N.NNNNNE+NN

37 - 48 +N,N1WNNE+NN

49 - 60 +N.NNNNNE+NN

61 - 72 +N.NNNNNE+NN

73 - 80 blank

340
5. Natural gas composition data blocks.

The data recorded by the on-line chromatographic system at Joliet are stored in a record pair. In many cases, there was not an analysis

performed by the chromatograph for each test run. Typically, two test

runs were made for each gas analysis recorded. Thus, the data in this

record pair corresponds to the most recent analysis recorded prior to

the run time listed in the header block. The format of the record pair

is given here:

Record # or description

Columns Format Comments

record I

date

run time

analysis time

mode

alarm

record II

C6+ mole percent

nitrogen cone

.

mole percent

methane cone

.

mole percent

CO2 cone

.

mole percent

ethane cone

.

mole percent

propane cone

.

mole percent

i -butane cone,

mole percent

n-butane cone

.

mole percent

i-pentane cone,

mole percent

n-pentane mole

percent

1

- 8 MM/DDAY

9 blank

10 - 17 HH:MM:SS

18 blank

19 - 22 HHMM

23 blank

24 - 27 XXXX

28 blank

29 - 36 XXXXXXXX

37 - 80 blank

1

- 7 NNN.NNN

8 blank

9

- 15 NNN.NNN

16 blank

17 - 23 NNN.NNN

24 blank

25 - 31 NNN . NNN

32 blank

33 - 39 NNN.NNN

40 blank

41 - 47 NNN . NNN

48 blank

49 - 55 NNN.NNN

56 blank

57 - 63 NNN.NNN

64 blank

65 - 71 NNN.NNN

72 blank

73 - 79 NNN . NNN

80 blank

341
Format for section IV. axixiliary file, for the High Reynolds Number Data

Base Project

For the High Reynolds Number data base, the auxiliary file contains the

nozzle calibration coefficients, and the pressure transducer daily

calibration data.

1. Sonic nozzle diameter and calibration coefficient data block.

The diameter and calibration coefficient data for the sonic nozzles

consists of a series of 11 records. These values were used uniformly

throughout the data reduction procedures employed in this project. The

format of the sonic nozzle data records is given here:

Record # or descriptionColumns Format Comments

record I

nozzle diameter

A coefficient

B coefficient

1

- 6 N.NNNN

7 blank

8

- 14 N.NNNNN

15 blank

16 - 22 +NN.NNN

23 - 80 blank

342
2. Static and differential pressure transducer calibration data blocks.

The pressure transducer calibration data are in the form of a header

record followed by a series of single data records. For the differential pressure calibrations, the header record identifies the calibration

observation number, date, time, transducer serial numbers for the two

transducers, and DDR-6000 serial numbers. The calibration observation

number is a sequential number which is one (1) at the beginning of any

given day, and is not related to the test run number. The format of the

differential pressure header record is given here:

Record # or descriptionColumns Format Comments

record I

calibration

observation number

date

time

DPI serial ntimber

DP2 serial number

number of data

points

1-2 NN

3 blank

4

- 11 MM/DD/YY

12 blank

13 - 20 HH:MM:SS

21 blank

22 - 27 XXXXXX

28 blank

29 - 34 XXXXXX

35 blank

36 - 37 NN

38 - 80 blank

343
The differential pressure data records for the calibration are a series

of records containing the DDR- 6000 zero and response values, and the

response values for each device . The total number of records in the

series is given in the header record, above. The format of the data

records is given here:

Record # or descriptionColumns Format Comments

record I

DDR-6000 zero 1

- 9 N.NNNNNNN

voltage

10 blank

DDR-6000 response 11 - 18 N.NNNNNN

voltage

19 blank

DPI response 20 - 26 N.NNNNN

voltage

27 blank

DP2 response 28 - 34 N.NNNNN

voltage

35 80 blank

344
For the static pressure calibrations , the header record Identifies the

calibration observation number, date, time, barometric pressure, the

serial number of the dead weight tester, the serial number of five

transducers, and the number of data records In the calibration. The

calibration observation number Is a sequential number which Is one (1)

at the beginning of any given day, and Is not related to the test run

number. The format of the static pressure header record Is given here;

Record # or descriptionColumns Format Comments

record I

calibration

observation number

date

time

barometric pressure

(psla)

DWT serial number

SPl serial number

SP2 serial number

SP3 serial niomber

SP4 serial number

SP5 serial number

number of data

records

NN

3 blank

4

- 11 MM/DD/YY

12 blank

13 - 20 HH:MM:SS

21 blank

22 - 28 NNN.NNN

29 blank

30 - 34 XXXXX

35 blank

36 - 41 XXXXXX

42 blank

43 - 48 XXXXXX

49 blank

50 - 55 XXXXXX

56 blank

57 - 62 XXXXXX

63 blank

64 - 69 XXXXXX

70 blank

71 - 72 NN

73 - 80 blank

345
The static pressure calibration data records are a series of records

containing the dead weight tester temperature, carrier mass, total mass,

and static pressure, and the response values for each of the five

transducers . The format of the data records is given here

:

Record # or descriptionColumns Format Comments

record I

DVJT temperature 1

- 7 NN.NNNN

(deg. F)

8 blank

DWT weight carrier 9

- 16 NN.NNNNN

mass (lb„)

17 blank

DWT total mass 18 - 24 NNN.NNN

(lb,)

25 blank

DWT static pressure 26 - 32 NNN.NNN

(psig)

33 blank

SPl response 34 - 40 N.NNNNN

voltage

41 blank

SP2 response 42 - 48 N.NNNNN

voltage

49 blank

SP3 response 50 - 56 N.NNNNN

voltage

57 blank

SP4 response 58 - 64 N.NNNNN

voltage

65 blank

SP5 response 66 - 72 N.NNNNN

voltage

73 - 80 blank

346
APPENDIX H

Operating Procedure for NGPLA

START UP - Gas in flow meters at line pressure.

In Computer Room :

1. Turn on Kepco Power Supply (it should indicate 30 volts).

2. Check that Ruska DDR6000 is on (3 hour warm-up required).

3. Turn on HP 3497A data logger.

4. Turn on window volt meter.

In Transducer Room :

5. Check that all side valves on the DP transducer 5 ways are closed

and all left hand side valves on the static transducer 5 ways are closed.

6a. Close all vents on static transducer 5 ways and open both small

valves

.

6b. Open right hand side valves on static transducer 5 ways.

6c. Check to make sure 3 small valves on all DP transducer 5 ways are closed. If these valves are closed and DP transducers were left

with 600 psi nitrogen gas, skip to step 10. SEE NOTE AT END OF

SHUT DOWN PROCEDURE.

7. Close the Whitey vent valve on DDR 5 way.

8. Open the three small valves on the DDR 5 way.

9. Open the side valves on the DDR 5 way.

10. Open pressure pump bjrpass (pull out little knob).

11. Back out pressure pump counter clockwise. (Return two turns

clockwise)

.

12. Back off Nj supply regulator at bottle valve for DP calibration.

13. Open N2 supply valve for DP transducer calibration (lowest Whitey).

14. At N2 supply regulator open bottle valve and slowly apply pressure

(100 psi/lO sec.) to equal gas line pressure.

In Computer Room :

15. Turn on computer power (CRT and printer power also come on). Enter

"B:<cr>" at CRT.

347
16. Punch the "Online Fault" button on the printer (green indicator

light comes on)

.

17. Enter "DO NGPL<cr>" at CRT (computer will display menu).

NOTE*: At any time during the day, the test loop pressure and

temperature values may be monitored from the menu. Enter

"l<cr>" at CRT to enter the monitor program.

To Calibrate the Pressure Transducer ;

18. Enter "2<cr>" at CRT.

Computer will display the last ENCAL analysis.

NOTE: If this does not occur within three minutes, punch "RESET" on computer and go to step 17.

19. Follow the instruction on the CRT.

NOTE*: The low range DP transducers are calibrated first, then the

high range, then the static transducers.

20. Zero differential is taken as valves are now set.

21. To get the requested differential pressure, close the right hand

small valve on the DDR 5 way 3 and push in pump b3rpass knob, adjust

the pump as required.

NOTE: Don't drive the window volt meter negative BELOW its zero

DP reading.

22. At the end of each DP transducer calibration open the DDR 5 way

right hand small valve and pull out the bypass knob to get zero DP

reading. Back out pressure pump (counter clockwise) between DP

calibrations and after last DP calibration. Turn pump back

clockwise two turns from stop.

23. At the end of each calibration the computer displays and prints

calibration data. Keep these prints.

NOTE* : If the standard deviation on the print-out is:

Low range DP: greater than .001

High range DP: greater than .01

Static pressures: greater than .6

the calibration must be rerun.

To rerun enter N when asked "if the calibration was NOT good and

you wish to redo it enter N else enter Y"

.

24. After calibrations are completed the computer returns to the menu.

348
IMPORTANT --IN TRANSDUCER ROOM - BEFORE YOU PROCEED

25. Close side valves on DDR 5 way. Close valve at N2 regulator.

25a. Very slowly open vent valve 1.

26. Open 2 small valves on any DP transducer 5 way, leave vent closed.

27. When the gas line is to pressure - open both side valves on all DP

transducer 5 ways

.

28. Close right hand side valves on all static transducer 5 ways.

28a. Close left small valves on static transducer 5 ways.

29. Close 2 small valves opened in step 26.

30. Open left hand side valves on all static transducer 5 ways.

31. Open vents on all static transducer 5 ways.

TRANSDUCERS are ready for data runs.

349
ORIFICE METER DATA ACQUISITION :

1 . When the NGPL menu is displayed after the pressure transducer

calibration, enter "3<cr>" at CRT to begin data acquisition.

NOTE*: Please be certain that the ENCAL is not about to print

before this step.

2. The computer will display the last ENCAL analysis. Touch the

space bar to continue.

3. The computer will display a message to the operator, followed by

the date on which the transducers were last calibrated.

4. The computer will then ask for the next run number, barometric

pressure, meter tube designation, orifice plate designation, and

each of four nozzle designations. Please follow the instructions

on the CRT.

NOTE*: If a nozzle location is not to be used for the current

flowrate, use item #12 for OFF.

5. The computer will then ask for comments from the operator. These

comments are particularly useful, for example, to note weather

conditions (rain starting during a test point or broken clouds with

intermittent sunshine) . In addition, the operator should note

anything that does not seem appropriate. Note that after all

comments have been made, an additional <cr> is required to

continue.

6. The pressure and temperature monitor will then be displayed. The

operator should wait for stable conditions before beginning data

acquisition. If a nozzle which should be OFF has a pressure drop

larger than 5 percent, an error message will be displayed. Follow

the instructions. If the orifice state pressure falls below 460

psia, the program will abort. If the orifice static pressure falls

between 460 and 480 psia, a warning will be displayed. Follow the

instructions.

7. Touch the space bar when the cursor is lit to begin data

acquisition. Data acquisition requires approximately six minutes.

8. After data acquisition, touch the <cr> to continue. If a new ENCAL

analysis is ready, the computer will run the program necessary to

read the analysis. Then the data acquisition program will run

again. For the same flowrate the program will continue with step

#5 of these instructions. After six points at the same flowrate,

the program will automatically stop and compute mean pressures,

temperatures, mass flowrate, and orifice Cp . Then the data will be

put into the database. Wordstar is then used to store operator

comments (see special instructions on use of Wordstar)

.

9. A new ENCAL analysis will be read before returning to the main

MENU.

350
10. If another flowrate is desired, enter "3<cr>" at CRT.

11. After six (6) flowrates or at the end of the day, it is necessary

to get a final ENCAL analysis, back up all data on two (2) floppy

diskettes, initialize the NGPL database files and put the computer

in remote mode for data transmissions. Enter "4<cr>" at CRT to

begin these tasks.

NOTE*: Please be certain that the final ENCAL analysis is later

than the one previously used for data acquisition. If

necessary, please wait (up to 13 minutes) before entering

"4<cr>" at CRT.

SHUT DOWN - Procedures for Transducers After Completion of Daily Runs

In Computer Room :

1. Turn off computer.

2. Turn off window volt meter.

3. IF YOU INTEND TO RUN TOMORROW - leave Kepco on - otherwise turn it

off.

In Transducer Room :

4. Close all left hand static pressure 5 way valves.

5. Open two small valves on any DP transducer 5 way, leave vent

closed.

6. Close both side valves on all DP transducer 5 ways.

7. Open vent at 5 way used in step 5 (bleed off gas).

8. Close valves opened in step 5 and 7.

9. Check that 3 small valves on DDR 5 way are open.

10. Close Whitey vent at DDR 5 way.

11. SLOWLY open side valves on DDR 5 way.

11a. Slowly open valve at N2 regulator to fill system with N2 to 600

psi.

12. When DP manifold is to 600 psi as set at N2 regulator, close bottle

valve

.

NOTE*: It is important to leave about 600 psi on DP manifold and

DDR as applying this pressure just prior to calibration can

cause considerable instability during the calibration of DP

transducers

.

351
NBS-n4A (REV. 2.8C) U.S. DEPT. OF COMM. BIBLIOGRAPHIC DATA

SHEET (See instructions)

. PUBLICATION OR

REPORT NO.

NIST/TN-1270

2. Performing Organ. Report No 3. Publication Date

September 1989

4. TITLE AND SUBTITLE

Measurements of Coefficients of Discharge for Concentric, Flange-Tapped, Square-Edged

Orifice Meters in Natural Gas Over the Reynolds Number Range 25,000 to 16,000,000

5. AUTHOR(S)

James R. Whetstone, William Go Cleveland, Blaine Ro Bateman, Charles Fo Sindt

6. PERFORMING ORGANIZATION (If joint or other than NBS. see instructions) NATIONAL INSTITUTE OF STANDARDS AND TECHNOLOGY

(formerly NATIONAL BUREAU OF STANDARDS)

U.S. DEPARTMENT OF COMMERCE

QArTHERSBURQ, MO) 20899

7. Contract/Grant No.

8. Type of Report & Period Covered

Final

9. SPONSORING ORGANIZATION NAME AND COMPLETE ADDRESS (Street. City. State. ZIP)

American Petroleum Institute

1220 L Street, NW

Washington, DC 20005

10. SUPPLEMENTARY NOTES

I I Document describes a computer program; SF-185, FlPS Software Summary, is attached.

11. ABSTRACT (A 200-word or less factual sumnr)ary of most significant information. If document includes a significant

bibliography or literature survey, mention it here)

This report describes Che data acquisition systems and procedures used

in Che American PecroLeum Inscitute (API) -sponsored orifice discharge coefficient project performed in nacural gas flows and conducted at Che test loop of the Natural Gas Pipeline Company of America (NGPL) in Joliet. Illinois. These systems follow the general design philosophy of

the companion intermediate Reynolds number project conducted in water

flows [1]. NBS provided Che measurement and data acquisition systems, maintained the resulting database, and calculated the results from thac dacabase.

Heasuremencs of orifice discharge coefficients for 6- and 10- inch diameter orifice meter runs were made using critical Venturis for mass flowrate measurement with associated measurement of pressures and temperatures. Eleven Venturis were calibrated at the Colorado Engineering Experiment Station, Inc. (CEESI). Measurements of absolute and differential pressure and temperature for venturi and orifice meter

conditions were made using an automated data acquisition system. Temperature and pressure measurements were directly related to U.S. national measurement standards. Dally calibration of absolute and differential pressure transducers using pressure working standards was designed into the measurement procedures.

Natural gas compositions were measured using on-line gas chromatography based on gravimetrically-prepared gas standards having compositions closely similar to those of the two gas stream compositions xised. Calculations of natural gas density and viscosity were made using a recently developed state-of-the-art equation of state [2] and a corresponding-states model of transport properties {3].

Collected over a 2-year period, the database contains tests on UU orifice places in 8 beta ratios for two meter sizes (6- and 10-inches). The database contains 1,345 valid test points.

NOTE; On August 23. 1988 with the signing of the Omnibus Trade and Competitiveness Act, the National Bureau of Standards (NBS) became the National Institute of Standards and Technology (NIST) . Since this report was written and reviewed before this change, references to NBS in

the body of the report have not been changed to NIST.

12. KEY WORDS (Six to twelve entries; alphabetical order; capitalize only proper names; and separate key words by semicolons)

Orifice discharge coefficient; natural gas metering

13. AVAILABILITY

fXI Unlimited

I I For Official Distribution. Do Not Release to NTIS

[Xn Order From Superintendent of Documents, U.S. Government Printing Office, Washington, D.C. 20402.

Q3] Order From National Technical Information Service (NTIS), Springfield, VA. 22161

14. NO. OF

PRINTED PAGES

364

15. Price

•tl US. GOVERNMENT PRINTTING OFFICE: 19e&- 261 -913 '0 5075 USCOMM-DC 6043-P80
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