Kansas Pipeline Company

Original Volume No. 1

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Effective Date: 05/11/1998, Docket: CP96-152-009, Status: Effective

Original Sheet No. 210 Original Sheet No. 210 : Effective




which is currently available or may become available at

any time during the term of the Transportation Agreement.


4.2 Such measurement, both volumetric and thermal, shall be

at a temperature of 60 degrees Fahrenheit and at a

pressure of 14.73 psia dry, and on the basis of the

methods prescribed and published by the American Gas

Association in conjunction with the ANSI/API 2530

Report as currently available and in accordance

with any subsequent amendments thereof accepted and

agreed upon between the parties if orifice meters are

used. If positive displacement or turbine meters

are used, measurement shall be performed in accordance

with AGA-7 as currently available and with any subsequent

amendments thereof accepted and agreed upon between the

parties. Btu content shall be determined by taking the

arithmetic average of the heating value as recorded by

a chromatograph or other method of determination generally

accepted in the industry. Flowing temperatures shall

be determined by a recording thermometer or EGM.


4.3 All measuring stations shall be acceptable to Kansas

Pipeline and Shipper and installed and operated to

conform to recognized industry standards, using flange

connections and, where necessary, pulsation dampening

equipment. Auxiliary equipment shall be installed

so as not to interfere with the measurement of

either party.


4.4 Either Kansas Pipeline or Shipper may witness the

installation or maintenance of the other's equipment.

Neither Kansas Pipeline nor Shipper shall be required to

verify accuracy more often than once during any 30 Day

period. If, upon test, accuracy is found to be within 2%

by volume (chromatograph within 0.5%), measurements taken

by such equipment shall be assumed to have been Accurate.

Any error exceeding these percentages shall require

correction to zero error of previous recordings back to

the date error began. If the beginning date of error is

unknown, correction shall extend to one-half

the time since the last test, not to exceed 16 Days.


4.5 Where wellhead compressors have been installed, the

maximum permissible Square Root Error Indicator (SREI)

shall be no greater than 1% for volumes less than 2 Mmcf