MSAR 82-04 A-104 QUALITY ASSURANCE PLAN to Environmental Protection Agency Industrial Environmental Research Laboratory Research Triangle Park, North Carolina 27711 DEMONSTRATION OF VAPOR CONTROL TECHNOLOGY FOR GASOLINE LOADING OF BARGES (Contract 68-02-3657) 11 January 1982 ------- MSAR 82-04 A-104 QUALITY ASSURANCE PLAN to Environmental Protection Agency Industrial Environmental Research Laboratory Research Triangle Park, North Carolina 27711 DEMONSTRATION OF VAPOR CONTROL TECHNOLOGY FOR GASOLINE LOADING OF BARGES (Contract 68-02-3657) 11 January 1982 Approval: Project Manager, S.S. Gross Q.A. Official, J. Wiley IERL Project Officer, S.J. Rakes Q.A. Officer, Gary Johnson ------- Section No. 1 Revision No. 4" Date: 11 January. 19821 Page 2 of 20 TABLE OF CONTENTS Page TITLE PAGE 1 TABLE OF CONTENTS 2 PROJECT DESCRIPTION . . 3 PROJECT ORGANIZATION AND RESPONSIBILITY 6 Q.A. OBJECTIVES ' ' 7 CALIBRATION, SAMPLING AND ANALYTICAL PROCEDURES 9 SAMPLE CUSTODY 13 DATA REDUCTION, VALIDATION AND REPORTING 14 INTERNAL QUALITY CONTROL CHECKS 15 PERFORMANCE AND SYSTEM- AUDITS 16 PREVENTIVE MAINTENANCE . 17 PROCEDURES TO ASSESS DATA ' 18 CORRECTIVE ACTION 19 QUALITY ASSURANCE REPORTS TO MANAGEMENT 20 APPENDIX DISTRIBUTION Name Title S.S. Gross MSAR Project Manager J. Wylie MSAR Q.A. Official S.J. Rakes EPA Project Officer ------- Section No. 1 Revision No. 4 Date: 11 January l Page 3 of zo PROJECT DESCRIPTION It is desirable to collect and treat the gasoline vapors emitted during barge loading operations. During Task 5 of this project, the effluent gasoline vapors will be collected and sent to an incinerator Reference is made to Work Plan dated 11 November 1980, Revised Work Plan 20 August 1981, and the Statement of Work on EPA Contract Number 68-02-3657 for more detailed de- scription of the Project. Tasks 1-4 of the project have been completed and did not involve monitoring or measurements. Task 6 includes a fugitive properties test. However, this test will most likely be adapted from existing tests and/ or techniques since only 80 hours have been allocated to this area. Therefore a QA. Plan is not required for Task 6. While the primary concern of the project is safety, the quantity of emitted gasoline vapors-and performance of the control system are needed for economic and feasibility evaluations. In addition, where applicable, the results of effluent stream analyses are to be entered into the Environ- mental Assessment Data System (EADS). A sketch of the project is shown in figure T. A 10,500 barrel barge will be moored by dockside. A flexible 6 inch 1ine ,connected to the on-shore vapor col- lection lines,will be bolted to the steel 6 inch vapor lines on the barge. Data will be taken continually as the barge is being filled with gasoline. ------- Section No. 1 Revision No. 4 Date: 11 January 1982 Page of !0 Incinerator Vapor Collection Line 1. Sampling point for the vapors of air- gasoline displaced from barge during loading. 2. % hydrocarbons in displaced vapors during loading. 3. Hydrocarbons in incinerator exhaust. Figure 1 - Schematic of Gasoline Barge Vapor Control ------- Section No. 1 Revision No. ""&.-.-». Date: U January 1982 Page 5 • of • zo After the barge is filled with gasoline, the collection of data will stop. The barge will be emptied by pumping the gasoline back to the storage tanks. After the barge is com- pletely emptied, the fill cycle will be repeated several days later. Data will once again be collected upon filling the barge. It will take approximately 5 hours to fill the barge and 8 hours to empty. It is expected 5 to 8 fill cycles will be performed for this project. The parameters which will be measured are the volume of vapors (CFM) displaced from the barge duri.ng filling, the percent total hydrocarbons in the vapors, the amount of liquid gasoline loaded (gallons), the total hydrocarbons in the in- cinerator exhaust (in ppm) and percent hydrocarbon at leak points in the vapor collection lines. The data from the project will be used to determine the amount of gasoline vapors emitted during barge loading, as well as the minimum performance of the vapor control unit. It is expected that the minimum performance of the incin- erator will be an emission level which does not exceed 35 milligrams of volatile organic compounds per 1 liter of gaso- line loaded. The safety, economic, and emissions data will be used to evaluate the suitability of vapor control during barge loading of gasoline. . . We anticipate start-up by 11 January 1982 and com- pletion 11 February 1982. ------- Section No. 1_ Revision No. 4 _ Date: 11 January 1982 Page 6 of 20~ PROJECT ORGANIZATION AND RESPONSIBILITY Below is the relationship of the Q.A. Official and Program Manager in the corporate organization. President - MSA \ Frank Dr. Frank W. Smith MSA Vice President RD&E Dr. J.W. Mausteller General Manager MSA Research . S.S. Gross Program Manager S.S. Gross F. Roehlich (on-site samplers) I William C. Hamilton MSA Vice President Manufacturing I Dr. R.A. Brown Q.A. Manager MSA I John Wylie Quality Assurance Official ------- Section No. ]_ Revision No. 4 Date: 11 January 1982 Page 7 of 20 Q.A. OBJECTIVES Q.A. objectives for Accuracy and Completeness are shown in Table 1. No objectives have been set for Precision since, due to costs, the standard deviation will not be calculated. The data which we will obtain should express a high degree of representativeness since the parameters will be measured continuously and directly as possible. It is unknown at this time with what degree of confidence one data set can be compared to another. Few previous attempts have been made to measure the conditions of the displaced vapors during gasoline barge loading. In addition, the displaced gasoline vapors can vary con- siderably due to ambient temperature, cleaned vs uncleaned barge and type of gasoline. Also, due to cost, Accuracy will not be calculated The objectives listed in Table 1 are expected equipment accuracies based upon equipment supplier specifications. ------- Table 1 - Q.A. Objectives Measurement Parameter (method) Gas volume (2A) Percent hydrocarbons in gas volume (25B) Volume of gasoline loaded (survey) Hydrocarbons in gas volume (25A) Leaks in vapor col- lection line (21) Reference _ _ _ _ _ Experimental Conditions air-vapors leav- ing barge air-vapors leav- ing barge liquid gasoline loaded exhaust from in- cinerator actual leakage Precision Std. Dev. Accuracy <±5% <±5% <±5% <±10* <±20% Completeness 100% 100% 100% 100% 90% ~o o ^o GO cu cu n> ro IQ r^- < O fD rt> -"• rl- _.. o O Z3 oo — C" . ro 'o DO ------- Section No. 1 Revision No. ?T Date: 11 January Page 9 of 20 CALIBRATION, SAMPLING AND ANALYTICAL PROCEDURES Five major parameters will be measured: 1. Volume of Air-Gasoline Displaced From Barge The proposed method of measurement'is EPA Method 2A (Appendix). We propose to use a turbometer with a tempera- ture and pressure recorder. Since the meter is calibrated at the factory, we will not conduct the calibration procedures in Method 2A. The meter will be placed directly in the on-shore vapor line just upstream of the flexible hose to the barge. This location was chosen as the most convenient in terms of its installation, removal and servicing. The barge filling time is approximately 5 hours. Therefore, while the filling rate is fairly constant, temperature or pressure changes could occur. Readings for the data sheet in figure 2A-1 of Method 2A will be taken every 30 minutes. As a check, we will compare the output from the turbometer with the volume of liquid gasoline loaded. While some vapor expansion may occur the rates of the volume of vapors from the turbometer over the volume of liquid gasoline loaded should be less than 1.4. 2. Hydrocarbon Concentration in the Vapors Displaced From the Barge We propose to use Method 25B (Appendix), which ------- Section No. 1 Revision No. Date: 11 January Page 10 of 20 uses a nondispersive infrared analyzer manufactured by MSA. A product data sheet on the instrument is enclosed. The sampling point for the explosion proof NDIR will be on the downstream side of the knockout tank approxi- mately 6 feet from the turbometer. A quarter inch sampling port is provided in the 6 inch vapor line. The analyzer will be located on a stand at the sampling .point. Approximately 2 feet of sampling line will be used. The NDIR is placed close to the sampling point to minimize vapor condensation. No sample conditioning will be done prior to analysis. The percent hydrocarbons in the displaced vapors is expected to vary from 0 to 55%. During the first 4-5 hours of filling the barge, the displaced vapors contain 0-15% hydrocarbons. During the last 0.5 hours, as the barge is almost full, the percent of hydrocarbons increases rapidly to 55%. The calibration gases will be ordered as Primary Standards traceable to NBS. These Primary Standards will be prepared gravimetrically using weights traceable to NBS for those cases where no Standard Reference Materials (SRM) exist, A strip chart recorder will be used to continuously record the output from the NDIR instrument. 3. Volume of Liquid Gasoline Loaded The volume of liquid gasol ine. 1 oaded will be'de- termined by a commercial surveyor. Because of the large quantity of gasoline transferred by barge, liquid meters are not used. Instead, an independent surveyor will measure the barge and the storage tank to determine the quantity of gaso- line transferred. The commercial surveyor for this program will probably be E.W. Saybolt and Co., Inc. ------- Section No. T_ Revision No. 4 Date: 11 January 1982 Page 11 of 20 The volume of liquid gasoline transferred can then be compared with the volume of vapor displaced to determine vapor growth as well as a basis for determining emission levels at the incinerator. 4.. Level of Hydrocarbons in Incinerator Exhaust The level of hydrocarbons in the incinerator ex- haust will be determined by using a flame ionization analyzer (Method 25A, with the exception of Protocol #1 in Section 4). The sampling point for the FID will be 24 inches from the end of the incinerator exhaust ductwork. A sampling port is provided for exhaust sampling at this point. The FID instrumentation will be on a stand with the sampling line approximately 3 feet in length. No sample conditioning will be done prior to analysis. The calibration gases will be purchased from a vendor and tested by MSAR or, if needed, the EPA to confirm the true concentration. The volume of air from the incinerator will be de- termined by measuring the intake volume to the incinerator blower. We will add the volume of vapors from the barge to determine the total quantity of air and vapors entering the incinerator. The temperature of the .incinerator exhaust will be used to make air volume corrections. We will measure the temperature with a dial gauge thermometer. The tempera- ture will be calibrated as in 4.2 of Method 2A. The blower moves over 21,000 cfm of air through the incinerator. Only a maximum of 300 cfm of vapors will ------- Section No. 1 Revision No. 3 Date: Tl January 1982 Page 12 of 20 arrive from the barge vapor line. Therefore, less than 2% of the gases moving through the incinerator will be from the barge. The volume of air to the blower will be measured using Reference Method 2 (pitot-tube velocity traverse). The blower runs at a constant speed. Therefore, there should not be gross variations in the volume of air.. There is no auxiliary fuel source except for a. pilot flame. Therefore, all unburned hydrocarbons found in the incinerator exhaust will be assumed to be from the gaso- line vapors displaced from the barge. 5. Leaks in the Vapor Collection Lines Leaks in the vapor collection lines will be de- termined using Method 21 (Appendix). ------- Section No. ] Revision No. 4 Date: 11 'January 1'982 Page 13 of ^ SAMPLE CUSTODY Data from the sampling instrument and support equip- ment will be placed in project notebooks and kept permanently in MSA corporate files. Copies of raw data will be included in Monthly Progress Reports. Since samples will not be collected nor subject to transport, no chain of custody is established. ------- Section No. Revision No. Date: 11 January Page 14 of 20 DATA REDUCTION, VALIDATION AND REPORTING The raw data from recorders and data sheets as well as the results of the calibration checks will be recorded in a project notebook on-site. Copies of the raw data and re- sults of the calibration checks will be-included in the Monthly Progress Reports. Data reduction will be conducted as specified in the enclosed methods. For each filling cycle the following information will be reported: 1. Total volume of gasoline vapors displaced. 2. A graph of the percent hydrocarbon versus time. 3. Volume of liquid gasoline transferred. 4. A graph of the percent hydrocarbon in the incinerator exhaust versus time. 5. Number and estimated size of the leaks during the filling cycle. 6. Performance of the incinerator by dividing the total weight of hydro- carbons from the incinerator exhaust by the volume of liquid gasoline loaded. The results will be reported as mg/Ji. The principal criteria for data validation will be pre and post-cycle calibrations conducted just before and after the barge is filled with gasoline. ------- Section No. 1 Revision No. 4 Date: M January \ySZ~~ Page 15 Of 20 INTERNAL QUALITY CONTROL CHECKS Internal quality control checks for this project will be the calibration standards specified for each measure- ment parameter. While no calibration check has been specified by MSAR for Method 2A, Method 21 has specifications for cali- bration precision in Section 2.1.2.2. Method 25A and 25B have calibration drift specifications in Section 5.2 ------- Section No. 1_ Revision No. 4 Date: 11 January 1982 Page 16 of 20 PERFORMANCE AND SYSTEM AUDITS A task group consisting of members from the EPA, Coast Guard, American Petroleum Institute and barge ope- rators has been formed to examine the project performance. Before actual field testing is initiated, the task group will review the barge vapor control system as well as the instrumentation used to obtain results. MSA's Quality Assurance Officer will also be present during the initial test to verify calibration and data collection procedures of the field personnel. An independent assessment of the data will be conducted by the task group. During the field tests, a meeting will be held with the task group to examine, discuss and evaluate the data. The task group may also decide to actually visit the test site, witness calibration and ope- rational procedures. The task group's comments and con- clusions will be included in the QA report to the EPA Project Officer. While the calibration techniques should provide a reliable internal performance audit of the analytical instruments, the EPA Project Officer may wish to have an independent assessment. . It will be the responsibility of the EPA to provide for the independent assessment. ------- Section No. 1 Revision No.T Date: .11 January 1982" Page 17 of 20 PREVENTIVE MAINTENANCE The instrumentation will, of course, be cleaned and calibrated before placing into the field. If problems are encountered during field tests, it is possible to re- move the instruments for repair at our MSA instrument repair group. The barge loading events can be easily rescheduled. to suit our data collection needs since the barge is dedi- cated to this program. MSA has instruction, service, and maintenance manuals for the NDIR, FID and the portable gas meter. The supplier of the turbometer has recommended installation, service and maintenance procedures which will be followed. ------- Section No. 1 Revision No.*T Date: 11 January 1982 Page 18 of 20 PROCEDURES TO ASSESS DATA The calibration procedures used in the referenced methods will be used to assess the data. As long as the in- strumentation fulfills the calibration requirement the data will be considered valid. Since the gas meter will not be calibrated before and after each cycle, the volume of vapors displaced from the barge will be compared with the volume of loaded liquid gasoline. These values should be fairly equal. Because of the limited number of cycles which will be conducted (5 to 8) as well as budget restraints, data will not be assessed for precision, accuracy nor completeness. Accuracy and completeness objectives shown in Table 1 are based on equipment supplier specifications and our intention to continuously monitor during a fill event. While it is our desire to collect the data con- tinually during a fill event, it is expected that at least one of the five to eight fill cycles will result in instrument malfunction. It is our goal to obtain at least four fill events with proper instrument performance. ------- Section No. 1 Revision No. J4 Date: 11 January 19'52 Page 19 of CORRECTIVE ACTION If the instruments are not meeting the required calibration guidelines, the span knob will be used to adjust the instrument. If proper instrument performance cannot be assured using the span adjustment, the Program Manager will be responsible for instrument repair or replacement. Mr. Roehlich and Mr. Gross will both be responsible for the calibration check and any corrective action. Mr. Gross will be responsible for approving such action. Because of the inability to conduct instrument re- pairs at the terminal (due to safety if the instrument is in an explosion-proof housing or because of weather), our only alternative to improve instrument performance is a span ad- justment. If span adjustment does not result in proper per- formance, the instrument will have to be taken to our Evans City instrument repair lab. ------- Section No. 1 Revision No.T Date: 11 January 1982 Page 20 of 20 QUALITY ASSURANCE REPORTS TO MANAGEMENT Midway through the field tests, data will be sent to the EPA Project Officer and the task group. At this time comments and suggestions will be solicited on the data 'gen- erated thus far. After the completion of the field tests, a complete set of field data will be sent to the EPA Project Officer. ------- APPENDIX ------- METHOD 2A. DIRECT MEASUREMENT OF GAS VOLUME r-v v\ THROUGH PIPES AND SMALL DUCTS ?/^ Vjl f^"- 1. Applicability and Principle "v*'" 1.1 Applicability. This method applies to the measurement of gas flow rates in pipes and small ducts, either in-line or at exhaust positions,.within the temperature range of 0 to 50eC. 1.2 Principle. A gas volume meter is used to directly measure gas volume. Temperature and pressure measurements are made to correct the volume to standard conditions. 2. Apparatus Specifications for the apparatus are given below. Any other apparatus that has been demonstrated (subject to approval of the Administrator) to be capable of meeting the specifications will be considered acceptable. 2.1 Gas Volume Meter. A positive displacement meter, turbine meter, or other direct volume measuring device capable of measuring volume to within 2 percent. The meter shall be equipped with a temperature gauge (+_ 2 percent of the minimum absolute temperature) and a pressure gauge (+_2.5 mm Hg). The manufacturer's recommended capacity of the meter shall be sufficient for the expected maximum and minimum flow rates at the sampling conditions. Temperature, pressure, corrosive characteristics, and pipe size are factors necessary to consider in choosing a suitable gas meter. 2.2 Barometer. A mercury, aneroid, or other barometer capable of measuring atmospheric pressure to within 2.5-mm Hg. In many cases, ------- the barometric reading may be obtained from a nearby national weather service station, in which case the station value (which is the absolute barometric pressure) shall be requested, and an adjustment for elevation differences between the weather station and the sampling point shall be applied at a rate of minus 2.5 mm Hg per 30-meter elevation increase, or vice-versa for elevation decrease. 2.3 Stopwatch. Capable of measurement to within 1 second. 3. Procedure 3.1 Installation. As there are numerous types of pipes and small ducts that may be subject to volume measurement, it would be difficult to describe all possible installation schemes. In general, flange fittings should be used for all connections wherever possible. Gaskets or other seal materials should be used to assure leak-tight connections. The volume meter should be located so as to avoid severe vibrations and other factors that may affect the meter calibration. 3.2 Leak Test. A volume meter installed at a location under positive pressure may be leak-checked at the meter connections by using a liquid leak detector solution containing a surfactant. Apply a small amount of the solution to the connections. If a leak exists, bubbles will form, and the leak must be corrected. • A volume meter installed at a location under negative pressure is very difficult to test for leaks without blocking flow at the inlet of the line and watching for meter movement. If this procedure is not possible, visually check all connections and assure tight seals. ------- 3.3 Volume Measurement. 3.3.1 For sources with continuous, steady emission flow rates, record the initial meter volume reading, meter temperature(s), meter pressure, and start the stopwatch. Throughout the test period, record the meter temperature(s) and pressure so that average values can be determined. At the end of the test, stop the timer and record the elapsed time, the final volume reading, meter temperature(s), and pressure. Record the barometric pressure at the beginning and end of the test run. Record the data on a table similar to Figure 2A-1. 3.3.2 For sources with noncontiguous, non-steady emission flow rates, use the procedure in 3.3.1 with the addition of the following. Record all the meter parameters and the start and stop times corresponding to each process cyclical or noncontiguous event. 4. Calibration 4.1 Volume Meter. The volume meter is calibrated against a standard reference meter prior to its initial use in the field. The reference meter is a spirometer or liquid displacement meter with a capacity consistent with that of the test meter. Alternative references may be used upon approval of the Administrator. Set up the test meter in a configuration similar to that used in the field installation (i.e., in relation to the flow moving device). Connect the temperature and pressure gauges as they are to be used in the field. Connect the reference meter at the inlet of the flow line, if appropriate for.the meter, and begin gas flow through the system to condition the meters. During this conditioning operation, check the system for leaks. ------- Plant Date Run Number Sample Location^ Barometric Pressure nan Hg. Operators Start Finish Meter Number Meter Calibration Coefficient Last Date Calibrated Time ' Run/clock' - Volume' Meter • ' reading Average Static pressure mm Hg Temperature . oC • • ... OK .... t : y !•••-.- » • i t . . i t i Figure 2A-1. Volume flov/ rate measurement data ------- The calibration shall be run over at least three different flow rates. The calibration flow rates shall be about 0.3, 0.6, and 0.9 times the meter's rated maximum flow rate. For each calibration run, the data to be collected include: reference meter initial and final volume readings, the test meter initial and final volume reading, meter average temperature and pressure, barometric pressure, and run time. Repeat the runs at each flow rate at least three times. Calculate the test meter calibration coefficient, Y , for each run as follows: (V - V ,)(t + 273) P rf - , rf r1 r Eq. 2A-1 Where: Ym = Test volume meter calibration coefficient, dimensionless. V- = Reference meter volume reading, m . V = Test meter volume reading, m . t = Reference meter average temperaturjs, "C. t = Test meter average temperature, °C. P. = Barometric pressure, mm Hg. P = Test meter average static pressure, mm Hg. f = Final reading for run. i = Initial reading for run. Compare the three Y values at each of the flow" rates tested m and determine the maximum and minimum values. The difference between ------- the maximum and minimum values at each flow rate should be no greater .than 0.030. Extra runs may be required to complete this requirement. If this specification cannot be met in six successive runs, the test meter is not suitable for use. In addition, the meter coefficients should be between 0.95 and 1.05. If these specifications are met at all the flow rates, average all the Y m values for an average meter calibration coefficient, T . The procedure above shall be performed at least once for each volume meter. Therefore, an abbreviated calibration check shall be completed after each field test. The calibration of the volume meter shall be checked by performing three calibration runs at a single, intermediate flow rate (based on the previous field test) with the meter pressure set at the average value encountered in the field test. Calculate the average value of the calibration factor. If the calibration has changed by more than 5 percent, recalibrate the meter over the full range of flow as described above. Note: If the volume meter calibration coefficient values obtained before and after a test series differ by more than 5 percent, the test series shall either be voided, or calculations for the test series shall be performed using whichever meter coefficient value (i.e., before or after) gives the greater value of pollutant emission rate. 4.2 Temperature Gauge. After each test series, check the temperature gauge at ambient temperature. Use an ASTM mercury-in-glass reference thermometer, or equivalent, as a reference. If the gauge being checked agrees within 2 percent (absolute temperature) of the reference, the temperature data collected in the field shall be considered valid. Otherwise, the test data shall be considered ------- invalid or adjustments of the test results shall be made, subject to the approval of the Administrator. 4.3 Barometer. Calibrate the barometer used against a mercury barometer prior to the field test. 5. Calculations Carry out the calculations, retaining at least one extra decimal figure beyond that of the acquired data. Round off figures after the final calculation. 5.1 Nomenclature Pb * Barometric pressure, mm Hg. P = Average static pressure in volume meter, mm Hg. Q = Gas flow rate, m /min, standard conditions. T"m = Average absolute meter temperature, *K. V = Meter volume reading, m . T = Meter calibration coefficient, dimensionless. m f = Final reading for run. i = Initial reading for run. s = Standard conditions, 20° C and 760-mm Hg. 0 = Elapsed run time, min. ------- 5.2 Volume. Vms = 0.3853 Tm ! 5.3 Gas Flow Rate. V Qs " -~ Eq. 2A-3 6. References 6.1 United States Environmental Protection Agency. Standards of Performance for New Stationary Sources, Revisions to Methods 1-8. Title 40, part 60. Washington, D.C. Federal Register Vol. 42, No. 160. August 18, 1977. 6.2 Rom, Jerome J. Maintenance, Calibration, and Operation of Isokinetic Source Sampling Equipment. U.S. Environmental Protection Agency. Research Triangle Park, N.C. Publication No. APTD-0576. March 1972. 6.3 Wortman, Martin, R. Vollaro, and P7R. Westlin. Dry Gas Volume Meter Calibrations. Source Evaluation Society Newsletter. Vol. 2, No. 2. May 1977. 6.4 Westlin, P.R. and R.T. Shigehara. Procedure for Calibrating and Using Dry Gas Volume Meters as Calibration Standards. Source Evaluation Society Newsletter. Vol. 3, No. 1. February 1978. ------- METHOD 21. DETERMINATION OF VOLATILE ORGANIC COMPOUND LEAKS 1. Applicability and Principle 1.1 Applicability. This method applies to the determination of volatile organic compound (VOC) leaks from organic process equipment. These sources include, but are not limited to, valves, flanges and other connections, pumps and compressors, pressure relief devices, process drains, open-ended valves, pump and compressor seal system degassing vents, accumulator vessel vents, and access door seals. 1.2 Principle. A portable instrument is used to detect VOC leaks from individual sources. The instrument detector is not specified, but it must meet the specifications and performance criteria contained in paragraph 2.1. 2. Apparatus 2.1 Monitoring Instrument. The monitoring instrument shall be as follows: 2.1.1 Specifications. a. The VOC instrument detector shall respond to the organic compounds being processed. Detectors which may meet this requirement include, but are not limited to, catalytic oxidation, flame ionization, infrared absorption, and photoionization. b. The instrument shall be intrinsically safe for operation in explosive atmospheres as defined by the applicable, U.S.A. Standards (e.g., National Electical Code by the National Fire Prevention Association) c. The instrument shall be able to measure the leak definition concentration specified in the regulation. ------- d. The instrument shall be equipped with a pump so that a continuous sample is provided to the detector. The nominal sample flow rate shall be 1-3 liters per minute. e. The scale of the instrument meter shall be readable to +5 percent of the specified leak definition concentration. 2.1.2 Performance Criteria. The instrument must meet the following performance criteria. The definitions and evaluation procedures for each parameter are given in Section 4. 2.1.2.1 The instrument response time must be 30 seconds or less. The response time must be determined for the instrument system configuration to be used during testing, including dilution equipment. The use of a system with a shorter response time than that specified will reduce the time required for field component surveys. 2.1.2.2 Calibration Precision: The calibration precision must be less than or equal to 10 percent of the calibration gas value. 2.1.2.3 Quality Assurance. The instrument shall be subjected to the response time and calibration precision tests prior to being placed in service. The calibration precision test shall be repeated every 6 months thereafter. If any modification or replacement of the instrument detector is required, the instrument shall be retested and a new 6-month quality assurance test schedule will apply. The response time test shall be repeated if any modifications to the sample pumping system or flow configuration is made that would change the response time. 2.3 Calibration Gases. The monitoring instrument is calibrated in terms of parts per million by volume (ppmv) of the compound specified in the applicable regulation. The calibration gases required for monitoring ------- and instrument performance evaluation are a zero gas (air, <3 ppmv VOC) and a calibration gas in air mixture approximately equal to the leak definition specified in the regulation. If cylinder calibration gas mixtures are used, they must be analyzed and certified by the manufacturer to be within +2 percent accuracy. Calibration gases may be prepared by the user according to any accepted gaseous standards preparation procedure that will yield a mixture accurate to within +2 percent. Alternative calibration gas species may be used in place of the calibration compound if a relative response factor for each instrument is determined so that calibrations with the alternative species may be expressed as calibration compound equivalents on the meter readout. 3. Procedures 3.1 Calibration. Assemble and start up the VOC analyzer and recorder according to the manufacturer's instructions. After the appropriate warmup period and zero or internal calibration procedure, introduce the calibration gas into the instrument sample probe. Adjust the instrument meter readout to correspond to the calibration gas value. If a dilution apparatus is used, calibration must include the instrument and dilution apparatus assembly. The nominal dilution factor may be used to establish a scale factor for converting to an undiluted basis. For example, if a nominal 10:1 dilution apparatus is used, the meter reading for a 10000 ppm calibration compound would be set at 1000. During field surveys, the scale factor of 10 would be used to convert measurements to an undiluted basis. 3.2 Individual Source Surveys. ------- 3.2.1 Case I - Leak Definition Based on Concentration Value. Place the probe inlet at the surface of the component interface where leakage could occur. Move the probe along the interface periphery while observing the instrument readout. If an increased meter reading is observed, slowly probe the interface where leakage is indicated until the maximum meter reading is obtained. Leave the probe inlet at this maximum reading location for approximately two times the instrument response time. If the maximum observed meter reading is greater than the leak definition in the applicable regulation, record and report the results as specified in the regulation reporting requirements. Examples of the application of this general technique to specific equipment types are: a. Valves—The most common source of leaks from valves is at the seal between the stem and housing. Place the probe at the interface where the stem exits the packing gland and sample the stem circumference. Also, place the probe at the interface of the packing gland take-up flange seat and sample the periphery. In addition, survey valve housings of multipart assembly at the surface of all interfaces where leaks can occur. b. Flanges and Other Connections—For welded flanges, place the probe at the outer edge of the flange-gasket interface and sample around the circumference of the flange. Sample other types of nonpermanent joints (such as threaded connections) with a similar traverse. c. Pumps and Compressors—Conduct a circumferential traverse at the outer surface of the pump or compressor shaft and seal interface. If the source is a rotating shaft, position the probe inlet within one centimeter of the shaftseal interface for the survey. If the housing configuration prevents a complete traverse of the shaft periphery, ------- sample all accessible portions. Sample all other joints on the pump or compressor housing where leakage can occur. d. Pressure Relief Devices—The configuration of most pressure relief devices prevents sampling at the sealing seat interface. For those devices equipped with an enclosed extension, or horn, place the probe inlet at approximately the center of the exhaust area to the atmosphere for sampling. e. Process Drains—For open drains, place the probe inlet at approximately the center of the area open to the atmosphere for sampling. For covered drains, place the probe at the surface of the cover interface and conduct a peripheral traverse. f. Open-Ended Lines or Valves—Place the probe inlet at approximately the center of the opening to the atmosphere for sampling. g. Seal System Degassing Vents and Accumulator Vents—Place the probe inlet at approximately-the center of the opening to the atmosphere for sampling. h. Access Door Seals—Place the probe inlet at the surface of the door seal interface and conduct a peripheral traverse. 3.2.2 Case II-Leak Definition Based on "No Detectable Emission." a. Determine the local ambient concentration around the source by moving the probe inlet randomly upwind and downwind at distance of one to two meters from the source. If an interference exists with this determination due to a nearby emission or leak, the local ambient con- centration may be determined at distances closer to the source, but in no case shall the distance be less than 25 centimeters. Note the ambient concentration and then move the probe inlet to the surface of ------- the source and conduct a survey as described in 3.2.1. If a concentration increase greater than 2 percent of the concentration-based leak definition is obtained, record and report the results as specified by the regulation. b. For those cases where the regulation requires a specific device installation, or that specified vents be ducted or piped to a control device, the existence of these conditions shall be visually confirmed. When the.regulation also requires that no detectable emissions exist, visual observations and sampling surveys are required. Examples of this technique are: i. Pump or Compressor Seals—If applicable, determine the type of shaft seal. Perform a survey of the local area ambient VOC concentration and determine if detectable emissions exist as described in 3.2.2.a. ii. Seal system degassing vents, accumulator vessel vents, pressure relief devices—If applicable, observe whether or not the applicable ducting or piping exists. Also, determine if any sources exist in the ducting or piping where emissions could occur prior to the control device. If the required ducting or piping exists and there are no sources of where the emissions could be vented to the atmosphere prior to the control device, then it is presumed that no detectable emissions are present. 4. Instrument Performance Evaluation Procedures 4.1 Definitions. 4.1.1 Calibration Precision. The difference between the average VOC concentration indicated by the meter readout for consecutive calibration repetitions and the known concentration of a test gas mixture. 4.1.2 Response Time. The time interval from a step change in VOC concentration at the input of the sampling system to the time at which ------- 90 percent of the corresponding final value is reached as displayed on the instrument readout meter. 4.2 Evaluation Procedures. At the beginning of the instrument performance evaluation test, assemble and start up the instrument according to the manufacturer's instructions for recommended warmup period and preliminary adjustments. If a dilution apparatus is used during field surveys, the evaluation procedure must be performed on the instrument- dilution system combination. 4.2.1 Calibration Precision Test. Make a total of nine measurements \ by alternately using zero gas and the specified calibration gas. Record the meter readings (example data sheet shown in Figure 21-1). 4.2.2 Response Time Test Procedure. Introduce zero gas into the instrument sample probe. When the meter reading has stabilized, switch quickly to the specified calibration gas. Measure the time from concen- tration switching to 90 percent of final stable reading. Perform this test sequence three times and record the results (example data sheet given in Figure 21-2). 4.3 Calculations. All results are expressed as mean values, calculated by: n *< Where: x. = Value of the measurements. z - Sum of the individual values. x = Mean value. n = Number of data points. ------- Instrument ID Calibration Gas Data Calibration = ppmv Run Instrument Meter Difference' ' No. Reading, ppm ppm 1. 2. 3. 4. 5. 6. 7. 8. 9. Mean Difference Calibration Precision = (1) Calibration Gas Concentration - Instrument Reading Figure 21-1. Calibration Precision Determination ------- Instrument ID Calibration Gas Concentration 90% Response Time: 1. Seconds 2. Seconds 3. Seconds Mean Response Time Seconds Figure 21-2. Response Time Determination ------- METHOD 25A - DETERMINATION OF TOTAL GASEOUS ORGANIC ^ r\Y\ CONCENTRATION.USING A FLAME IONIZATION ANALYZER -A>\ ^ 1. Applicability and Principle 1.1 Applicability. This method applies to the measurement of total gaseous organic concentration of vapors consisting of nonmethane alkanes, alkenes, and/or arenes (aromatic hydrocarbons). The concentration is expressed in terms of propane (or other appropriate organic compound) or in terms of organic carbon. 1.2 Principle. A gas sample is extracted from the source, through a heated sample line, if necessary, and glass fiber filter to a flame ionization analyzer (FIA). Results are reported as concentration equivalents of the calibration gas organic constituent, carbon, or other organic compound. 2. Definitions 2.1 Measurement System. -The total equipment required for the determination of the gas concentration. The system consists of the following major subsystems: 2.1.1 Sample Interface. That portion af the system that is used for one or more of the following: sample acquisition, sample transportation, sample conditioning, or protection of the analyzer from the effects of the stack effluent. ------- 2.1.2 Organic Analyzer. That portion of the system that senses organic concentration and generates an output proportional to the gas concentration. 2.2 Span Value* The upper limit of a gas concentration measurement range that is specified for affected source categories in the applicable part of the regulations. For convenience, the span value should correspond to 100 percent of the recorder scale. 2.3 Calibration Gas. A known concentration of a gas in an appropriate diluent gas. 2.4 Zero Drift. The difference in the measurement system output readings before and after a stated period of operation during which no unscheduled maintenance, repair, or adjustment took place and the input concentration at the time of the measurements were zero. 2.5 Calibration Drift. The difference in the measurement system output readings before and after a stated period of operation during which no unscheduled maintenance, repair, or adjustment took place and the input concentration at the time of the measurements was a mid-level value. 3. Apparatus A schematic of an acceptable measurement system is shown in Figure 25A-1. The essential components of the measurement system are described below: 3.1 Organic Concentration Analyzer. A flame ionization analyzer (FIA) capable of meeting or exceeding the specifications in thv method. ------- 3.2 Sample Probe. Stainless steel, or equivalent, three-hole rake type. Sample holes shall be 4 mm in diameter or smaller and located at 16.7, 50, and 83.3 percent of the equivalent stack diameter. 3.3 Sample Line. Stainless steel or Teflon* tubing to transport the sample gas to the analyzers. The sample line should be heated, if necessary, to prevent condensation in the line. 3.4 Calibration Valve Assembly. A three-way valve assembly to direct the zero and calibration gases to the analyzers is recommended. Other methods, such as quick-connect lines, to route calibration gas to the analyzers are applicable. 3.5 Particulate Filter. An in-stack or an out-of-stack glass fiber filter is recommended if exhaust gas particulate loading is significant. An out-of-stack filter should be heated to prevent any condensation. 3.6 Recorder. A strip-chart recorder, analog computer, or digital recorder for recording measurement data. The minimum data recording requirement is one measurement value per minute. Note: This method is often applied in highly explosive areas. Caution and care should be exercised in choice of equipment and installation. 4. Calibration and Other Gases Gases used for calibrations, fuel, and combustion air (if required) are contained in compressed gas cylinders of stainless steel or aluminum. Preparation of calibration gases shall be done according Mention of trade names on specific products does not constitute endorsement by the Environmental Protection Agency. ------- to the procedure in Protocol No. 1, listed in Reference 9.2. The pressure in the gas cylinders is limited by the critical pressure of the subject organic component. As a safety factor, the maximum pressure in the cylinder should be no more than half the critical pressure. Additionally, the manufacturer of the cylinder should provide a recommended shelf life for each calibration gas cylinder over which the concentration does not change more than +_ 2 percent from the certified value. Calibration gas usually consists of propane in air or nitrogen and is determined in terms of the span value. The span value is established in the applicable regulation and is usually 1.5 to 2.5 times the applicable emission limit. If no span value is provided, use a span value equivalent to 1.5 to 2.5 times the highest expected concentration. Organic compounds other than propane can be used following the above guidelines and making the appropriate corrections for carbon number. 4.1 Fuel. A 40 percent IW60 percent He or 40 percent H«/60 percent N« gas mixture is recommended to avoid an oxygen synergism effect that reportedly occurs when oxygen concentration varies significantly from a mean value. 4.2 Zero Gas. High purity air with less than 0.1 parts per million by volume of organic material (propane or carbon equivalent). 4.3 Low-level Calibration Gas. An organic calibration gas with a concentration equivalent to 25 to 35 percent of the applicable span value. ------- 4.4 Mid-level Calibration Gas. An organic calibration gas with a concentration equivalent to 45 to 55 percent of the applicable span value. 4.5 High-level Calibration Gas. An organic calibration gas with a concentration equivalent to 80 to 90 percent of the applicable span value. 5. Measurement System Performance Specifications 5.1 Zero Drift. Less than +_ 1 percent of the span value. 5.2 Calibration Drift. Less than +_ 1 percent of the span value. 6. Pretest Preparations 6.1 Selection of Sampling Site. The location of the sampling site is generally specified by the applicable regulation or purpose of the test; i.e., exhaust stack, inlet line, etc. The sample port shall not be located within 1.5 meters or 2 equivalent diameters (whichever is less) of the gas discharge to the atmosphere. 6.2 Location of Sample Probe. Install the sample probe so that the probe is centrally located in the stack, pipe, or duct and is sealed tightly at the stack port connection.^ 6.3 Measurement System Preparation. Prior to the emission test, assemble the measurement system following the manufacturer's written instructions in preparing the sample interface and the organic analyzer. Make the system operable. FIA equipment can be calibrated for almost any range of total organics concentrations. For high concentrations of organics (>1.0 percent by volume as propane) modifications to most commonly ------- available analyzers are necessary. One accepted method of equipment modification is to decrease the size of the sample to the analyzer through the use of a smaller diameter sample capillary. Direct and continuous measurement of organic concentration is a necessary consideration when determining any modification design. 6.4 Calibration. Immediately prior to the test series, introduce zero gas and high-level calibration gas at the calibration valve assembly. Adjust the analyzer output to the appropriate levels, if necessary. Then introduce low-level and mid-level calibration gases successively to the measurement system. Record the analyzer responses for all four gases and develop a permanent record of the calibration curve. This curve shall be used in performing the post-test drift checks and in reducing all measurement data during the test series. No adjustments to the measurement system shall be conducted after the calibration and before the drift check (Section 7.3). If adjustments are necessary before the completion of the test series, perform the drift checks prior to the required adjustments and repeat the calibration following the adjustments. If multiple electronic ranges are to be used, each additional range must be checked with a mid-level calibration gas to verify the multiplication factor. 7. Emission Measurement Test Procedure 7.1 Organic Measurement. Begin sampling at the start of the test period, recording time notations and any required process information as appropriate. In particular, note on the recording chart periods of process interruption or cyclic operation. ------- 7.2 Drift Determination. Immediately following the completion of the test period, or if adjustments are necessary for the measurement system during the test, reintroduce the zero and mid-level calibration gases, one at a time, to the measurement system at the calibration valve assembly. (Make no adjustments to the measurement system until after the drift checks are made.) Record the analyzer response. If the drift values exceed the specified limits, invalidate the test run preceding the check and repeat the test run following corrections to the measurement system. Alternatively, recalibrate the test measurement system as in Section 6.4 and report the results using the calibration data that yield the highest corrected emission concentration. 8. Organic Concentration Calculations Determine the average organic concentration in terms of ppmv as propane or other calibration gas. The average shall be determined by the integration of the output recording over the period specified in the applicable regulation. If results are required in terms of ppmv as carbon, adjust measured concentrations using Equation 25A-1. Cc • K C meas Eq. 25A-1 • ------- Where: C - Organic concentration as carbon, ppmv. C*a=e ~ Organic concentration as measured, ppmv. meas K - Carbon equivalent correction factor, K a 2 for ethane. K = 3 for propane. K = 4 for butane. 9. References 9.1 Measurement of Volatile Organic Compounds - Guideline Series. U.S. Environmental Protection Agency. Research Triangle Park, N.C. Publication No. EPA-450/2-78-041. June 1978. p. 46-54. 9.2 Traceability Protocol for Establishing True Concentrations of Gases Used for Calibration and Audits of Continuous Source Emission Monitors (Protocol No. 1). U.S. Environmental Protection Agency, Environmental Monitoring and Support Laboratory. Research Triangle Park, N.C. June 1978. 10 pgs. 9.3 Gasoline Vapor Emission Laboratory Evaluation - Part 2. U.S. Environmental Protection Agency, Office of Air Quality Planning and Standards. Research Triangle Park, N.C. Report No. 75-GAS-6. August 1975. 32 pgs. ------- PROBE HEATED SAMPLE LINE CALIBRATION VALVE PARTICULATE FILTER SAMPLE PUMP ORGANIC ANALYZER AND RECORDER •STACK Figure 25A-1. Organic Concentration Measurement System. ------- METHOD 25B - DETERMINATION OF TOTAL GASEOUS ORGANIC CONCENTRATION USING A NONDISPERSIVE IMFRARED ANALYZER 1. Applicability and Principle 1.1 Applicability. This method applies to the measurement of total gaseous organic concentration of vapors consisting primarily of nonmethane alkanes. (Other organic materials may be measured using the general procedure in this method, the appropriate calibration gas, and an analyzer set to the appropriate absorption band.) The concentration is expressed in terms of propane (or other calibration •> gas) or in terms of organic carbon. r 1.2 Principl . A gas sample is extracted from the source, through a heated sample line and glass fiber filter to a nondispersive infrared analyzer (NDIR). Results are reported as equivalents of the calibration gas or as carbon equivalents. 2. Definitions The terms and definitions are the same as for Method 25A. 3... Apparatus - The apparatus are the same as for Method 25A with the exception of the following: 3.1 Organic Concentration Analyzer. A nondispersive infrared analyzer designed to measure alkane organics and capable of meeting or exceeding the specifications in this method. 4. Calibration Gases The calibration gases are the same as are required for Method 25A, Section 4. No fuel gas is required for an NDIR. ------- 5. Measurement System Performance Specifications 5.1 Zero Drift. Less than £2 percent of the span value. 5.2 Calibration Drift. Less than £ 2 percent of the span value. 6. Pretest Preparations 6.1 Selection of Sampling Site. Same as in Method 25A, Section 6.1. 6,2 Location of Sample Probe. Same as in Method 25A, Section 6.2. 6.3 Measurement System Preparation. Prior to the emission test, assemble the measurement system following the manufacturer's written instructions in preparing the sample interface and the organic analyzer. Make the system operable. 6.4 Calibration. Same as in Method 25A, Section 6.4. 7. Emission Measurement Test Procedure Proceed with the emission measurement immediately upon satisfactory completion of the calibration. 7.1 Organic Measurement. Same as in Method 25A, Section 7.1. 7.2 Drift Determination. Same as in Method 25A, Section 7.2. 8. Organic Concentration Calculations The calculations are the same as in Method 25A, Section 8. 9. References The references are the same as in Method 25A, Section 9. ------- INSTRUMENTS Lira" Modei 303 Luft-type Infrared Analyzer Application The Lira* Infrared Analyzer, Model 303, is a selective, stable, and economical instrument specifically designed to provide accurate and continuous analysis of a gas or vapor. The Model 303 is capable of measuring a single component in a complex mixture of gases or vapors. It can detect any gas or vapor that absorbs infrared energy. (Elemental diatomic gases such as hydrogen, oxygen, nitrogen, chlorine, and the rare gases are not infrared active.) The Model 303 Analyzer is unaf- fected by silicones, thus is an ideal instrument for the detection of combustible solvent vapors where the presence of silicones prevents the use of other combustible gas analyzers. Also, Lira Model 303 is capable of measuring many hazard- ous gases in low concentrations such as carbon monoxide, halo- genated hydrocarbons, carbon dioxide, etc. Other applications include furnace atmosphere control, humidity dew point measurement, chemical and petrochemical process stream anal- ysis, and solvent vapor detection. Description The Lira Model 303 Analyzer operates on the Nondispersive Infrared (NDIR) principle. Twin beams of infrared radiation are projected through parallel cells; one beam traverses the sample cell, the other beam the comparison cell. The emergent radiation is directed into a single detector cell that is responsive at an infrared wavelength where the component of interest absorbs infrared and background component(s) is transparent. An interrupter, or "chopper," located between the radiation source and the cells, alternately blocks radiation to the sample cell and the comparison cell. When the infrared beams are equal, an equal amount of radiation enters the detector cell from each beam. Beam Chopper Infrared Sources Filter Cells Sealed In Detector Gas Sensitive Membrane When the gas to be analyzed is introduced into the sample cell, it absorbs (and reduces) the radiation reaching the detector via the sample beam. Consequently, the beams become unequal, the radiation entering the detector flickers as the beams are alternated, and the detec- tor gas expands or contracts in response to the flicker. This movement of the detector gas causes the microphone membrane to move in response. The membrane movement varies the condenser microphone's electrical capacity which, in turn, electronically results in electrical signal proportional to the difference between the two radiation beams: i.e., concentration of the component of interest. The signal is then amplified and fed to the indicating meter. The signal can be used as input to external re- corders, alarms, or control loops. Datasheet 07-0518 ------- Typical specifications Performance Principle of operation: Nondisper- sive infrared (NDIR) spectroscopy Speed of response: 90% of final reading in 5 seconds (optional 90% in 3 seconds) Noise level: Less than 1 % of full scale Zero drift: Less than 1% of full scale in 24 hours Span drift: Less than 1 % of full scale in 24 hours Calibration curve: Determined and provided for each instrument Repeatability: ±1% of full scale Linearity: Normally +5 to +10% nonlinear Temperature effect: Analyzer inter- nally thermostated at 140-145° (60-63°C) permitting operation from 40-115°F(4-45°C) ambient temperatures Electronics: Completely solid-state, plug-in circuit boards for amplifier, power supply, source voltage regula- tor and signal output Controls: Precision multiturn potentiometers with counting dials for zero and span Operating Power requirements: 60 VA, 120V, 60 Hz (50/Hz designs available) Warm-up time: 30 minutes. Instru- ment provided with lamp (heater) to indicate temperature control cycle Output: Millivolt—field adjustable—0-10, 0-100 mV; any standard potenti- ometer recorder can be employed Voltage (optional)—0-1, 0-5, 0-10 Vdc, 50 mA maximum Current (optional)—0-1,0-5,1-5, 0-20, 0-50,10-50 mA; 10 Vdc— output commons can be floating or grounded Line voltage variation: Analyzer provided with a constant voltage power supply to compensate for line voltage variations from 95 V to 130 V Vibration effect: Unaffected by normal plant vibration Remote mounting: Recorder can be mounted as much as 2500 ft from analyzer and remote zero and span controls can be field installed Note: This Data Sheet contains only a general description of the Lira Model 303 Infrared Analyzer. While uses and per- formance capabilities are described, under no circumstances should this product be used except by qualified, trained personnel and not until the instructions, labels, and other literature accompanying the product have been carefully read and understood and the precautions therein set forth followed. Only they contain the complete and detailed information concerning this product. _ — Sample \ Va NPT, I (28.58) t 3V4 (82.55) 1 / / Outlet / female / \ F / Sample Inlet Va NPT, female ..... y , Tt v._ U=, s° Vz d'< Si • 1C - % Dia. Knockout (22.23) Electrict Cover \" 7/8 o/a. H . removed to \ 11 s/7ow terminal \ ^^ sfr/p Tt \ -V Cfl t « • 7 i g « ii |3-^i I^ISI^I^ISISrSi^l (_) i o ®| s> <§ I®1 o ^^ or/, > i/£ ole 1 (& •3 ntry— (22.23) t 6 (> 1 t fc 71.45) t ^ (234.95) >.7) Dimensions in inches; millimeters shown in ( ). Calibration: Calibration accom- plished by using known gas samples for zero and span of instrument Span check: Precision resistor in source circuit simulates gas pres- ence in Lira cell, actuated by push- button on front panel Options: Dual Range: Instrument can be provided with dual range unit for secondary ranges up to a 20x factor Linearization:'A linearization circuit can be provided to correct cali- bration curve to within ±1 % of a straight line response Physical Construction: Analyzer complete with integral meter in general pur- pose case. Recorder optional; portable Dimensions: 19%6"L x 91/4"D x 6%"H (491 x 235x172 mm) Cut out dimensions: Front panel: 81/4 x 10Vz x 1 % (210 x 267 x 48 mm) Cut out: 6% x 91/2 (175 x 242 mm) Weight: 37 Ib (17 kg) • Tubing: Polyurethane and/or nylon, does not absorb water or hydrocarbons Inlet-Outlet: Va" NPT Sample cells: Aluminum block with internally gold-plated stainless steel insert; maximum length up to 8" in aluminum housing; cells also avail- able in stainless steel and other materials Windows: Window materials are sapphire, quartz, calcium fluoride, barium fluoride, etc., depending on application. Ordering information For formal quotation please contact MSA, describing compound to be analyzed and approximate stream analysis. rttttiT MIIU Mine Safety Appliances Company Instrument Division 600 Penn Center Boulevard Pittsburgh, Pennsylvania 15235 Atlanta, Boston, Chicago, Cleveland, Detroit, Houston, Los Angeles, Milwaukee, New York City, Philadelphia, Pittsburgh, San Francisco, St. Louis, MSA CANADA. Downsview, Ontario (Metro Toronto) urnm Data Sheet 07-0518 Printed in U.S.A. 789 (L) ------- |