Great Lakes Gas Transmission Limited Partner

Second Revised Volume No. 1

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Effective Date: 01/01/2008, Docket: RP08- 78-000, Status: Effective

Second Revised Sheet No. 18 Second Revised Sheet No. 18 : Effective

Superseding: First Revised Sheet No. 18

 

 

GENERAL TERMS AND CONDITIONS

____________________________

(continued)

 

7. MEASUREMENT EQUIPMENT

 

7.1

(a) The volume of gas delivered at the point(s) of receipt and at the point(s) of delivery shall be

measured by:

 

(i) An orifice meter designed, installed, maintained and operated as recommended in the latest issue

of American National Standard ANSI/API 2530 (American Gas Association Gas Measurement Report No.

3), entitled "Orifice Metering of Natural Gas and Other Related Hydrocarbon Fluids", as such

publication may be revised from time to time (hereinafter referred to as "AGA Report No. 3")

(revisions will be incorporated within a reasonable time period); or

 

(ii) A turbine meter designed, installed, maintained and operated as recommended in the latest issue

of American Gas Association Transmission Measurement Committee Report No. 7 entitled

"Measurement of Fuel Gas by Turbine Meters", as such publication may be revised from time to

time (hereinafter referred to as "AGA Report No. 7") (revisions will be incorporated within a

reasonable time period); or

 

(iii) A positive displacement meter installed and operated in accordance with generally accepted

industry practices; or

 

(iv) An Ultrasonic meter designed, installed, maintained and operated as recommended in the latest

issue of American Gas Association Transmission Measurement Committee Report No. 9 entitled

"Measurement of Gas by Multipath Ultrasonic Meters", as such publication may be revised from

time to time (hereinafter referred to as "AGA Report No. 9")(revisions will be incorporated

within a reasonable time period).

 

(b) The construction and installation of the metering facilities shall be in accordance with the

recommendations and specifications set forth by the reports specified in Section 7.1(a)(i),(ii), and

(iv) hereof or by the meter manufacturer specified in Section 7.1(a)(iii) hereof.

 

7.2 Auxiliary measuring equipment shall be installed, maintained and operated in accordance with generally

accepted industry practices. Chromatographs calculating the heating value (Btu) of the gas shall be

programmed having the Gas Processors Association (GPA) Standard 2145 Table of Paraffin Hydrocarbons and

Other Components of Natural Gas.

 

7.3 The volume of gas delivered at each point of receipt and point of delivery shall be calculated by means of

an electronic flow computer located at, or by the processing of meter charts recorded at, each point of

receipt or each point of delivery. The calculation or processing, in either case, shall be performed in

the following manner:

 

(a) When the measuring equipment is an orifice meter, the flow of gas through the meter shall be computed

in the manner recommended in AGA Report No. 3, properly using all factors set forth therein.

 

(b) When the measuring equipment is a turbine meter, the volume of gas delivered through the meter shall

be computed in the manner recommended in AGA Report No. 7, properly using all factors set forth

therein.

 

(c) When the measuring equipment is a positive displacement meter, the volume of gas delivered through

the meter shall be computed by properly applying, to the volume delivered at flowing gas pressures

and temperatures, correction factors for (1) absolute static pressure, (2) flowing gas temperature,

(3) compressibility ratio and (4) specific gravity.

 

(d) When the measuring equipment is an ultrasonic meter, the volume of gas delivered through the meter

shall be computed in the manner recommended in AGA Report No. 9, properly using all factors set forth

therein.

 

7.4 The operator, for purposes of this subsection, shall be the owner of the equipment referenced herein, or

the agent of the owner, or such other person as the parties may agree in writing.