DOCSLIB.ORG

Rules & Regulations Prescribing Standards for Gas Utilities, Master

Total Page：16

File Type：pdf, Size：1020Kb

Download full-text PDF Read full-text
Rules & Regulations Prescribing Standards for Gas Utilities, Master 815-RICR-20-00-1 TITLE 815 – DIVISION OF PUBLIC UTILITIES AND CARRIERS CHAPTER 20 – NATURAL GAS AND JURISDICTIONAL PROPANE SUBCHAPTER 00 - N/A PART 1 – Standards for Gas Utilities, Master Meter Systems and Jurisdictional Propane Systems 1.1 Incorporated Materials A. These regulations hereby adopt and incorporate 49 C.F.R. Parts 40 (2018) and 49, 49 C.F.R. Parts 190-199 (2018) by reference, not including any further editions or amendments thereof and only to the extent that the provisions therein are not inconsistent with this Part. B. These regulations hereby adopt and incorporate the following National Fire Protection Association (NFPA) publications by reference, not including any further editions or amendments thereof and only to the extent that the provisions therein are not inconsistent with this Part: 1. NFPA 54 National Fuel & Gas Code (2018), 2. NFPA 58 Storage and Handling of Liquefied Petroleum Gases (2017), 3. NFPA 59 Storage and Handling of Liquefied Petroleum Gases at Utility Gas Plants (2018), and 4. NFPA 59A Production Storage and Handling of Liquefied Natural Gas (LNG) (2016). C. These regulations hereby adopt and incorporate the following American Gas Association (AGA) publications by reference, not including any further editions or amendments thereof and only to the extent that the provisions therein are not inconsistent with this Part: 1. AGA Manual for the Determination of Supercompressibility Factors for Natural Gas, Project NX-19 (A.G.A. Catalog No. L00340) (1962), and 2. AGA Compressibility and Supercompressibility for Natural Gas and Other Hydrocarbon Gases, Transmission Measurement Committee Report No. 8 (1992). D. These regulations hereby adopt and incorporate American National Standards Institute (ANSI) standards ANSI B109 (1986) and ANSI B40.1 (1986) by reference, not including any further editions or amendments thereof and only to the extent that the provisions therein are not inconsistent with this Part. E. These regulations hereby adopt and incorporate the following parts of the American National Standards Institute/American Petroleum Institute (ANSI/API) 2530, Orifice Metering of Natural Gas and Other Related Hydrocarbon, AGA Report No. 3, by reference, not including any further editions or amendments thereof and only to the extent that the provisions therein are not inconsistent with this Part: 1. Part I, "General Equations and Uncertainty Guidelines," (AGA Catalog No. XQ9017) (1990), 2. Part II, "Specification and Installation Requirements," (AGA Catalog No. XQ9104) (1991), 3. Part III, "Natural Gas Applications," (AGA Catalog No. XQ9210) (1992), 4. Part IV, "Background Development, Implementation Procedures, and Sub- Routine Documentation for Empirical 33 Flange-Tapped Discharged Coefficient Equation," (AGA Catalog No. XQ9211) (1992). F. These regulations hereby adopt and incorporate specific American National Standards Institute (ANSI) standards listed below by reference, not including any further editions or amendments thereof and only to the extent that the provisions therein are not inconsistent with this Part. 1. ANSI B109.1, Diaphragm Type - Gas Displacement Meters, Under 500 Cubic Feet per Hour Capacity, (AGA Catalog No. X69218) (1992), 2 ANSI B109.2, Diaphragm Type - Gas Displacement Meters, 500 Cubic Feet per Hour Capacity and Over, (AGA Catalog No. X69219) (1992), and 3. ANSI B109.3, "Gas Displacement Meters, Rotary Type," (AGA Catalog No. X69220) (1992). G. These regulations hereby adopt and incorporate the American Society for Testing and Materials (ASTM) publications by reference, not including any further editions or amendments thereof and only to the extent that the provisions therein are not inconsistent with this Part: 1. ASTM specification D-1826 "Calorific Value of Gases in Natural Gas Range by Continuous Recording Calorimeter," (D1826-88) (1988), 2. ASTM specification D-1945 "Method for Analysis of Natural Gas by Gas Chromatography," (D1945-91) (1991), and 3. ASTM specification D-3588 "Method for Calculating Calorific Value and Specific Gravity (Relative Density of Gaseous Fuels)," (D3588-91) (1991). 1.2 Application of Rules and Regulations A. This Part shall apply to all LDC’s, Master Meter Systems, and Jurisdictional Propane Systems engaged in the business of manufacturing, distributing, selling or transmitting natural or other gas by pipeline in the State of Rhode Island; currently, there is one LDC, 40 Master Meter Systems, and 20 Jurisdictional Propane Systems in operation within the State of Rhode Island, all of whom are subject to all or specified portions of these rules. B. These Rules and Regulations replace the following existing Division rules and regulations: 1. Rules & Regulations Prescribing Standards for Gas Utilities, effective date June 8, 1966, 2. Regulations Regarding Gas Pipeline Safety Enforcement Procedures Docket No. D-86-4, effective date March 13, 1986, 3. Control of Drug Use in Natural Gas and Liquified Natural Gas, effective date May 10, 1990, and 4. the Rules and Regulations Prescribing Standards for Gas Line Abandonment & Leakage Survey Procedures Docket No. D-86-2, effective date May 21, 1986. 5. These four existing compilations of rules and regulations of the Division are hereby rescinded upon the effective date of this document. C. This Part is intended to supplement, and shall be interpreted in a fashion consistent with, the Federal rules set out in the Code of Federal Regulations (C.F.R.) incorporated above in § 1.1(A) of this Part, specifically in 49 C.F.R Parts 40 and 190-199. The Federal safety standards and regulations for the transportation of natural and other gas by pipeline, established pursuant to the Natural Gas Pipeline Safety Act of 1968, as amended (49 U.S.C. § 1671, et seq.) by the United States Department of Transportation and contained in 49 C.F.R. Parts 40 and 190-199, are incorporated by reference above. Since the State of Rhode Island is bound to comply with Federal law concerning gas utilities, and has been delegated enforcement authority by the Federal government, amendments to the Federal rules are incorporated by reference and shall be effective as part of these rules without further action. LDC’s shall comply with all of the rules set out herein. D. This Part shall be amended or repealed, and applications therefore shall be made, in accordance with R.I. Gen. Laws §§ 39-3-33 and 42-35-1, and Part 00- 00-1 of this Title (Division of Public Utilities and Carriers Rules of Practice and Procedure). A written application may be made to the Division for temporary or permanent exemption from any provision of this Part for good cause shown. E. “Master Meter Systems” and “Jurisdictional Propane Systems” are only required to comply with the safety requirements of 49 C.F.R. Parts 191-192 Pipeline Safety Regulations, incorporated above in § 1.1(A) of this Part, NFPA 58 Storage and Handling of Liquefied Petroleum Gases, and NFPA 59 Storage and Handling of Liquefied Petroleum Gases at Utility Gas Plants, incorporated above in § 1.1(B) of this Part, the § 1.12 of this Part relating to Enforcement Procedures section contained herein, and § 1.14 of this Part, the Natural Gas Telephonic Notice Reporting Requirements. 1.3 Definitions A. The definitions set out in 49 C.F.R. §§ 190.3, 191.3, and 192.3 are incorporated by reference above in § 1.1(A) of this Part, except as augmented or modified below. Unless the context otherwise requires, the following words as used herein shall have the following meanings: 1. “Abandoned” means that the service line is physically disconnected (cut- off) at the main, or at the distribution line that is the source of supply if the pipe is not a main, and the pipe is made from material other than plastic or cathodically-protected steel. If the service line is plastic or cathodically- protected steel, it may be cut off at or in close proximity to a property line and made into a stub. When the service line is abandoned, the LDC shall remove the meter and assembly. Should access to these not be readily available, the LDC shall make multiple attempts to gain access for removal. The end of the operator's pipe that is within the customer's building must be cut off below ground and sealed outside the building or must be sealed by inserting a device within the service line to a point that is outside the building wall or foundation. Provisions must be made so that the seal or device cannot be readily removed. When the end of the operator's pipe is located above ground outside the building, the aboveground segment must be removed and the remaining segment below ground sealed. In any case, the pipeline's above or below ground entry point into the building or foundation must be sealed after the pipe has been removed. The pipeline shall be purged and sealed in accordance with 49 C.F.R. § 192.727(b). 2. “Accessory” means any meter reading device, which is mechanically or non-mechanically attached to a meter and could affect its accuracy, used to display, record, or transmit meter information to a remote location or any associated meter correction device, either remote or attached, used to adjust the reading of a meter index. 3. “Administrator” means the Administrator of the Rhode Island Division of Public Utilities and Carriers. 4. “AMR” means an automated meter-reading device. 5. “British Thermal Unit" or "BTU” means a unit of heat equal to the amount of heat required to raise one pound of water one degree Fahrenheit at one atmosphere pressure; equivalent to 251.997 calories. 6. “Commission” means the Rhode Island Public Utilities Commission. 7. “Cubic foot” a. The term cubic foot means the volume of gas which occupies one (1) cubic foot of space at a temperature of 60° Fahrenheit and an absolute pressure of 14.73 pounds per square inch (known as standard conditions) with deviation there from, for varying pressure and temperature being in accordance with Boyle’s Law and Charles’ Law.
Load more

Recommended publications
  • Biomass-Derived Hydrogen from a Thermally Ballasted Gasifier
    Proceedings of the 2002 U.S. DOE Hydrogen Program Review NREL/CP-610-32405 Biomass-Derived Hydrogen from a Thermally Ballasted Gasifier Robert C. Brown, Glenn Norton, Andy Suby, Jerod Smeenk, Keith Cummer, and Josh Nunez Center for Sustainable Environmental Technologies Iowa State University Ames, IA 50011-3020 INTRODUCTION The goal of this project is to optimize performance of an indirectly heated gasification system that converts switchgrass into hydrogen-rich gas suitable for powering fuel cells. We have developed a thermally ballasted gasifier that uses a single reactor for both combustion and pyrolysis. Instead of spatially separating these processes, they are temporally isolated. The producer gas is neither diluted with nitrogen or the products of combustion. The heat released during combustion at 850°C is stored as latent heat in the form of molten salt sealed in tubes immersed in the fluidized bed. During the pyrolysis phase, which occurs at temperatures between 600 and 850°C, the reactor is fluidized with steam or recycled producer gas rather than air. Heat stored in the phase change material is released during this phase of the cycle to support the endothermic reactions of the pyrolysis stage. Because air is not used during the gas-producing phase of the cycle, nitrogen does not dilute the product gas, resulting in relatively high concentrations of hydrogen and carbon monoxide in the producer gas compared to conventional gasifiers. The carbon monoxide, along with steam used to fluidize the reactor, can be shifted to additional hydrogen by the water-gas shift reaction. Objectives in the first year include: • Determine whether switchgrass is a suitable fuel for the ballasted gasifier.
    [Show full text]
  • Lng Flow Calibration Facilities
    LNG FLOW CALIBRATION FACILITIES Oswin Kerkhof, VSL Mijndert van der Beek, VSL Peter Lucas, VSL Maria Mirzaei, VSL Gerard Blom, VSL Gertjan Kok, VSL Keywords: calibration, flow, flowmeter, custody transfer, measurement, uncertainty, accuracy, transport fuel, quality measurement, 1. Introduction Reliable, accurate and commonly agreed measurement methods are a first requirement for the trade of goods. For the large scale LNG distribution chain there is a commonly agreed measurement practice as described in various ISO standards and in the GIIGNL “Custody transfer handbook”. In comparison with other commodities like natural gas or gasoline the total uncertainty on measured energy is very high for LNG. The LNG industry is therefore committed to improve their measurement accuracies to reduce their financial risks and to optimize their mass and energy balances. As an extension of the traditional distribution chain for LNG a new market of professional consumers is developing with LNG as transport fuel. In this case there is no commonly agreed measurement practice and the metrological framework is not yet in place. This will be a showstopper for the roll-out of the LNG as transport fuel because laws will be enforcing protection of (professional) consumers. For small scale LNG the legal metrology framework will lay down requirements on traceability to national standards and will define maximum permissible measurement errors. This is not the case for large scale LNG where the industrial players are assumed to take care of their own business interests. For this reason the development of an LNG calibration facility is a crucial step and urgently required for the development of the small scale LNG distribution chain.
    [Show full text]
  • Field Reference Manual, 2015
    CALIFORNIA DEPARTMENT OF FOOD AND AGRICULTURE DIVISION OF MEASUREMENT STANDARDS FIELD REFERENCE MANUAL 2015 California Code of Regulation Title 4, Division 9 Chapter 1 Tolerances and Specifications for Commercial Weighing and Measuring Devices NIST Handbook 44 Sections 3.30. Liquid-Measuring Devices through 3.39 Hydrogen Gas-Measuring Devices DISCLAIMER This document represents the Division of Measurement Standards’ field manual for enforcing regulations pertaining to weights and measures in California. This field manual is not to be considered as the official Code of Regulations, as published by Barclays Law Publishers. NOTE: Language in Handbook 44 that is not adopted is annotated “[NOT ADOPTED]” in this document. NOTE: Requirements are different than, or in addition to, the requirements of Handbook 44 are included in the appropriate section this document. They are shaded, bordered, and numbered in the 4002 series to differentiate them from the Handbook 44 requirements. To find the latest online version of the California Code of Regulations (CCR) Title 4, Division 9, visit the California Office of Administration Law (OAL) at: http://ccr.oal.ca.gov/linkedslice/default.asp?SP=CCR-1000&Action=Welcome The CCR may also be accessed at http://oal.ca.gov/ by selecting the link Titled “California Code of Regulations” under the list of “Sponsored Links” in the left column on the OAL Home page. For information concerning the contents of this document, please contact the Division of Measurement Standards by e-mail at [email protected]. NIST Handbook 44 (2015 Edition) - Specifications, Tolerances, and Other Technical Requirements for Weighing and Measuring Devices as adopted by the 98th National Conference on Weights and Measures July 2014 is available at: www.nist.gov/pml/wmd/pubs/hb44.cfm 3.30.
    [Show full text]
  • Guidelines for Gas Meters & Manifolds
    Guidelines for Gas Meters & Manifolds * By carefully following attached suggestions, you will help us get your meters set on the first trip and avoid costly delays related to return trips (for which you are being charged $65 per trip). CoServ Gas Engineering (940) 270-7585 For Gas Emergencies or Leaks call: (844) 330-0763 CoServ Gas Meters and Manifolds Builder & Customer Requirements 1) Gas Meter Planning Guidelines a. The size of gas metering and regulating facilities varies widely depending upon the gas-load needs of each residence, business or commercial building. Due to the parameters associated with meter and regulator selection, it is imperative that the Customer, or the Customer’s agent, contact the assigned CoServ Gas representative prior to construction to determine the exact requirements for specific installations, including location and space requirements. Consulting with us early in the process may eliminate the need for changes to the gas metering facilities or gas Main Extensions or relocation of gas risers at a later date with additional delays and expense to Builder or Customer. 2) Meter Selection Criteria a. To assure proper operation, each gas meter must be the proper size and type for the maximum gas demand and required pressure. The maximum gas demand is determined by adding the Btu input ratings of all gas burning devices that may possibly be operating simultaneously. Furnaces, space heaters, water heaters, boilers, pool heaters, fireplace logs, gas clothes dryers, gas lights, and gas generators should be included at their maximum input ratings. b. The type of meter installed can also vary depending upon the Customer’s usage factors, e.g., what type of business, hours of operation, critical operations, etc.
    [Show full text]
  • Sub-Metering of Natural Gas Flexible Flow Measurement Delivers Improved Accuracy and Substantial Savings
    WHITEPAPER Sub-Metering of Natural Gas Flexible Flow Measurement Delivers Improved Accuracy and Substantial Savings by: Scott Rouse, VP Product Management, Sierra Instruments, Inc fter a decade of remarkable growth, This natural gas boom highlights the importance A the United States has become the for utility companies to provide homes, world’s number one producer of natural gas, businesses, and mid-to-large size facilities and its largest consumer, with consumption in with accurate natural gas billing. Traditionally, 2019 at 31 trillion cubic feet. This high growth utility companies have used diaphragm meters rate is expected to continue. For example, to measure natural gas usage, which is then electricity generation using natural gas has charged to customers on their monthly energy increased from 17% to 35% of total electrical bill. Although diaphragm meters are a trusted consumption, and is likely to increase to 50% billing mechanism by utility companies, they by mid-century. may not provide customers with the most accurate natural gas bill. Diaphragm meters have SUB-METERING OF NATURAL GAS WHITEPAPER limitations in natural gas measurement. If the WHAT IS NATURAL GAS? diaphragm meter does not ac curately measure Natural gas is the cleanest burning fossil the natural gas, this can result in utility companies fuel, producing by-products of mostly carbon overcharging customers. dioxide and water vapor. It is used extensively To avoid this problem, many mid-to-large-size in power generation, industrial and commercial facilities use flow meters to sub-meter their applications, and for home utility and heating. natural gas usage to validate the diaphragm Natural gas is primarily a mixture of methane, meters’ readings and more efficiently allocate ethane and propane, but those components energy.
    [Show full text]
  • Performance of a Pilot Scale Biomass Gasification and Producer
    Iowa State University Capstones, Theses and Graduate Theses and Dissertations Dissertations 2010 Performance of a pilot scale biomass gasification and producer gas combustion system using feedstock with controlled nitrogen content Sharan Sethuraman Iowa State University Follow this and additional works at: https://lib.dr.iastate.edu/etd Part of the Mechanical Engineering Commons Recommended Citation Sethuraman, Sharan, "Performance of a pilot scale biomass gasification and producer gas combustion system using feedstock with controlled nitrogen content" (2010). Graduate Theses and Dissertations. 11725. https://lib.dr.iastate.edu/etd/11725 This Thesis is brought to you for free and open access by the Iowa State University Capstones, Theses and Dissertations at Iowa State University Digital Repository. It has been accepted for inclusion in Graduate Theses and Dissertations by an authorized administrator of Iowa State University Digital Repository. For more information, please contact [email protected]. Performance of a pilot scale biomass gasification and producer gas combustion system using feedstock with controlled nitrogen content by Sharan Sethuraman A thesis submitted to the graduate faculty in partial fulfillment of the requirements for the degree of MASTER OF SCIENCE Major: Mechanical Engineering Program of Study Committee: Song-Charng Kong, Major Professor Terrence Meyer Gap Yong Kim Iowa State University Ames, Iowa 2010 ii TABLE OF CONTENTS LIST OF FIGURES ..................................................................................................................................
    [Show full text]
  • Anaerobic Digester / Biogas Operator Guidebook
    EPA 430-B-20-003 Anaerobic Digester/Biogas System Operator Guidebook A Guidebook for Operating Anaerobic Digestion/Biogas Systems on Farms in the United States November 2020 AgSTAR Operator Guidebook PREFACE U.S. EPA AgSTAR Program AgSTAR is a voluntary outreach program that encourages the implementation of anaerobic digestion (AD) projects in the agricultural and livestock sector to reduce methane (CH4) emissions from agricultural residuals including livestock waste. AD projects can be cost-effective mitigation techniques and provide numerous co-benefits to the local communities where they are installed, including environmental, energy, financial, and social sector benefits. AgSTAR is a collaborative program sponsored by the U.S. Environmental Protection Agency (EPA) and the U.S. Department of Agriculture (USDA) that promotes the use of biogas recovery systems to reduce CH4 emissions from livestock waste. As an education and outreach program, AgSTAR disseminates information relevant to livestock AD projects and synthesizes it for stakeholders who implement, enable, or purchase AD projects. The program’s goals are to provide information that helps stakeholders evaluate the appropriateness of an AD project in a specific location, to provide objective information on the benefits and risks of AD projects, and to communicate the status of AD projects in the livestock sector. Through the AgSTAR website (www.epa.gov/agstar) and at public events and other forums, AgSTAR communicates unbiased technical information and helps create a supportive environment for the implementation of livestock AD projects. AgSTAR provides technical input to the USDA Rural Energy for America Program, which provides grant funding for AD systems at farms.
    [Show full text]
  • Industrial Gas Meter with M-Bus for Compressed Air, Natural Gas, Biogas
    Flow Industrial gas meter with M-Bus for compressed air, natural gas, biogas... Compressed air and natural gas meters with M-Bus now also directly from the manufacturer. CS Instruments GmbH & Co. KG was the OEM-manufacturer of the ENDYS AIR compressed air meter with M-Bus from 2010 to the end of 2017. The ENDYS AIR products have been marketed exclusively through Hochhut GmbH, wich now works with another manufacturer. The CS Instruments GmbH & Co. KG now offers the products themselves. The successor product of ENDYS AIR now offers all the possibilities of digitization and is the ideal consumption meter for Industry 4.0. The successor products of the well-known ENDYS AIR company Hochhuth have been metrologically improved and completely revised and in addition to the M-Bus interface also have the following additional outputs or bus systems: • Modbus RTU • Modbus TCP or TCP PoE • Profibus, Profinet • 4..20 mA and pulse • Hard (in preparation) The VA 520, VA 500, VA 550 and VA 570 industrial gas meters with M-Bus are the ideal compressed air meters or consumption meters for natural gas, biogas, methane, nitrogen, argon, carbon dioxide for consumption measurement and flow measurement. VA 520, VA 500, VA 550, VA 570 with M-Bus are ideal for conversion or retrofitting and for new installations of gas meters, com- pressed air meters, flow meters, etc. to existing or new energy management software according to DIN ISO 50001 and DIN ISO 16247 and building management systems. Advantages: • Direct display in Nm3/h, or NI/min and temperature in C° • Calorimetric measuring principle - no additional pressure and temperature measurement necessary • High measurement accuracy ¼ to 3 inches • VA 500 and VA 550 insert version from ½ inch to DN 400 / DN 500 www.cs-instruments.com 1 Flow VA 520 Compressed air meter with M-Bus Display twist able by 180°C e.g.
    [Show full text]
  • Trac 2. CO Meter 3. 4 Mulm-‐Gas Detector
    HyaHsville Volunteer Fire 2epartment Training Gas Meters 7as Meter9s Carried on the Squad 1. Gas-­‐Trac 2. CO Meter 3. 4 Mul5-­‐Gas$Detector$8MiniMax$X4$Mul5$Gas$ Detector) 11/22/09 Gas$Meters$ Ga%*5rac General*@nformaon ,he$Gas$,rac$is$an$instrument that is$capable$of$ detec5ng$combus5ble$gases.$,he$Gas$,rac is factory$calibrated$for$methane$in$the$air.$,he$ alarm$Iill$be$set oJ$Ihen$the$methane$ concentra5on$in$the$air$approaches$20$percent of$ the$loIer$explosive$limit 11/22/09 Gas$Meters$ Most Common 2etectable 7ases • Acetone • Smoke$ • Alcohol$ • Steam$ • Ammonia • Industrial$Solvents$ • BenNene • Uet Fuel$ • Ethane$ • Lacquer$,hinner$ • Ethylene$ • Methane$ • Gasoline$ • Naphtha • Propane$ • Hydrogen$Sul[de$ • Refrigerants$ 11/22/09 Gas$Meters$ 11/22/09 Gas$Meters$ Direcons*/o*Dse 1. ,urn$the$Gas-­‐,rac$on$in$a non-­‐contaminated$ atmosphere$$$ 2. ,he$ready$light should$come$on$to$determine$ that the$meter$is$ready$for$use$ 3. ,he$L.E.D.$labeled$“Slight]$Iill$light Ihen$.1%$of$ the$gas$is$detected.$,he$“Medium]$light Iill$ light Ihen$1%$of$the$gas$is$detected.$,he$ “Alarm]$light Iill$come$on$Ihen$.%$of$the$gas$ is detected. 11/22/09 Gas$Meters$ Direcons*/o*Ds)*EConB.uedF 2.$,o$pinpoint a leak$source_$adjust the$“,icS$Rate]$ control$for$the$sloIest uniform$5cSing$sound.$ ,he$5cS$rate$Iill$then$vary_$corresponding$to$the$ change$in$gas$concentra5on$detected.$,he$5cS$ rate$is$independent of$the$lights$and$alarm_$ Ihich$are$calibrated$to$appropriate$gas$ concentra5ons.$ 11/22/09 Gas$Meters$ CO Meter ,he$C0$Meter$should$be$turned$on$in$an$ uncontaminated$atmosphere.$ ase$common$sense$Ihen$using$the$meter_$if$ people$are$complaining$of$head$aches_$SCMA$ must be$Iorn.$ Donbt rely$on$home$detectors_$as$they$are$not alIays$accurate.$ 11/22/09 Gas$Meters$ CO EIposure Chart EAll 2ata Based on 1 Hour EIposuresF • MNO*334*E3#0ts per*4illion) $no$health$risSc$normal$C0$levels$ COP in$air.
    [Show full text]
  • An Indirect Measurement Method for Gas Consumption of a Diaphragm Gas Meter Based on Gas Pressure Signal Detection
    applied sciences Article An Indirect Measurement Method for Gas Consumption of a Diaphragm Gas Meter Based on Gas Pressure Signal Detection Zhao Han , Xiaoli Wang *, Baochen Jiang and Xiaopeng Chen School of Mechanical, Electrical and Information Engineering, Shandong University, Weihai 264209, China; [email protected] (Z.H.); [email protected] (B.J.); [email protected] (X.C.) * Correspondence: [email protected]; Tel.: +86-138-6302-6640 Received: 19 March 2019; Accepted: 31 May 2019; Published: 18 June 2019 Featured Application: This indirect measurement method can be utilized to improve the remote meter reading technology for gas meter. Abstract: At present, the remote meter reading problem for a large number of existing domestic diaphragm gas meters has not been reliably solved. The diaphragm gas meter uses a physical structure to measure gas consumption, so the main problem of remote meter reading is the digitization of gas consumption. Although it is possible to digitize the consumption data by modifying the internal structure of the gas meter or adding sensors, thereby realizing the function of remote meter reading, the modification process is complicated, the modification cost is high, and manual meter reading can only be used for the existing diaphragm gas meters. For this reason, this paper proposes an indirect measurement method of gas consumption based on gas pressure signal detection. The method can digitalize the metering results of the mechanical diaphragm gas meter and develop a state detection function by analyzing the pressure signal of the outlet of the meter without modifying the internal structure of a meter, thus addressing the key difficulties in the construction of a gas meter remote meter reading system.
    [Show full text]
  • Natural Gas Meter Installations
    Hibbing Public Utilities Policy Number: CUST094gasmeterinstall Date: May 1, 2004 Subject: NATURAL GAS METER INSTALLATIONS General Requirements Gas meters used to measure the quantity of natural gas used by a customer are owned by the HPUC. The HPUC and the customer will jointly determine the location of all natural gas meters. The HPUC will install, set, and maintain the natural gas meter. Only authorized HPUC personnel can set a meter, turn a meter on or off (except in emergencies), connect a meter to the main gas system, o remove a natural gas meter. Residential Natural Gas Installations The location of residential meters will be jointly determined by the HPUC and then customer in accordance with the following guidelines: 1. Meter installations must comply with all local, state, or federal regulations as stipulated in CFR Part 192. 2. Meters will be located in a safe location that is readily accessible for meter reading and repair. 3. Outside meter locations are mandatory. Outside meters will be installed by a meter set bracket. 4. Inside gas meters are prohibited. 5. Meters and associated relief valves will not be closer than 3 feet to any source of ignition such as electric meters, switches, and transformers. 6. Meter locations will avoid water taps, electric facilities, air intake vents, edges of sidewalks, and driveways. 7. Meters must be installed at least 6 inches above finished grade level. Adopted by Commission Action Pg. 2 – Custo94gasmeterinstall Commercial and Industrial Natural Gas Meter Installations 1) Factors that determine the design of a commercial or industrial natural gas meter installation include: a.
    [Show full text]
  • Section 3.33. Hydrocarbon Gas Vapor-Measuring Devices1
    Handbook 44 - 2007 3.33. Hydrocarbon Gas Vapor-Measuring Devices Section 3.33. Hydrocarbon Gas Vapor-Measuring Devices1 A. Application A.1. - This code applies to devices used for the measurement of hydrocarbon gas in the vapor state, such as propane, propylene, butanes, butylenes, ethane, methane, natural gas and any other hydrocarbon gas/air mix. (Amended 1984, 1986, 1988, and 1991) A.2. - This code does not apply to: (a) Liquid-measuring devices used for dispensing liquefied petroleum gases in liquid form (see Sec. 3.32; Code for Liquefied Petroleum Gas and Anhydrous Ammonia Liquid-Measuring Devices). (b) Natural, liquefied petroleum, and manufactured-gas-vapor meters when these are operated in a public utility system. (c) Mass flow meters (see Sec. 3.37. Code for Mass Flow Meters) (Added 1994) A.3. - See also Sec. 1.10; General Code requirements. S. Specifications S.1. Design of Indicating and Recording Elements and of Recorded Representations. S.1.1. Primary Elements. S.1.1.1. General. - A device shall be equipped with a primary indicating element and may also be equipped with a primary recording element. S.1.1.2. Units. - A volume-measuring device shall indicate, and record if equipped to record, its deliveries in terms of cubic meters or cubic feet, or multiple or decimal subdivisions of cubic meters or cubic feet. (Amended 1972 and 1991) S.1.1.3. Value of Smallest Unit. - Volume-Measuring Devices: The value of the smallest unit of indicated delivery, and recorded delivery if the device is equipped to record, shall not exceed: (a) 1 m3 (1000 dm3) (100 ft3) when the maximum rated gas capacity is less than 100 m3/h (10 000 ft3/h); (b) 10 m3 (1000 ft3) when the maximum rated gas capacity is 280 m3/h (10 000 ft3/h) up to, but not including, 1700 m3/h (60 000 ft 3/h); (c) 100 m3 (10 000 ft3) when the maximum rated gas capacity is 1700 m3/h (60 000 ft3/h) or more.
    [Show full text]