Common use of Measurement Equipment and Procedures Clause in Contracts

Measurement Equipment and Procedures. 6.1. The volume of Gas will be measured by a primary and secondary measurement device that is accepted by industry, state, and federal regulatory agencies. The most common primary devices are orifice or ultrasonic meter tubes. These devices shall comply with the American Petroleum Institute - Manual of Petroleum Measurement Standards, 14.3, American Gas Association Report No. 3, and Report No. 9, (Latest Revisions) where applicable. The secondary measurement device shall be an electronic flow meter (“EFM”) that includes a temperature recording system. The EFM shall meet and be capable of performing volume calculations according to the current standards prescribed in the American Gas Association Report No. 3, Orifice Metering of Natural Gas and Other Hydrocarbon Fluids, Parts 1-4, and shall comply with the American Petroleum Institute — Manual of Petroleum Measurement Standards, Chapter 21, Section 1 — Electronic Gas Measurement, (Latest Revisions). 6.2. The unit of volume for measurement of Gas delivered hereunder shall be one thousand (1,000) Cubic feet of Gas at a base temperature of sixty degrees Fahrenheit (60°F) and at an absolute pressure base of 14.73 psia. 6.3. For purposes of measurement hereunder, the atmospheric (barometric) pressure shall be the average actual atmospheric pressure for the geographical area as determined by the Processor. If the pressure transmitter being used is capable of measuring actual atmospheric pressure, then actual atmospheric pressure may be used. 6.4. Processor shall determine the Gas stream composition, specific gravity, and gross Heating Values based on any of the following: spot samples, composite samples, on-line Gas chromatograph analysis or portable Gas chromatograph analysis. The component analysis of the Gas shall be performed by Gas chromatography in accordance with GPA 2261 and 2172 or any pertinent revisions thereto or replacements thereof. Gas samples shall be obtained in accordance with the procedures set forth in the Gas Processor’s Association Standard 2166 (Latest Revision) “Obtaining Natural Gas Samples for Analysis by Gas Chromatography” and American Petroleum Institute 14.1 Section 1 (Latest Revision). 6.5. The sampling frequency will be no less than semi-annually or more often if deemed necessary by Processor. 6.6. Tests for oxygen, carbon dioxide, sulphur, and hydrogen sulfide content of the Gas delivered hereunder shall be made as often as deemed necessary by Processor, by means commonly used and accepted in the industry. 6.7. Deviation from ▇▇▇▇▇’▇ Law at the pressure, specific gravities and temperatures upon delivery shall be calculated by the NX-19 as outlined or described in the American Gas Association Report “Manual for the Determination of Super Compressibility” or AGA 8, Gross or Detail methods as outlined or described in the AGA Report No. 8 entitled “Compressibility Factors of Natural Gas and Other Related Hydrocarbon Gases”. 6.8. All measuring equipment, housing, devices, and materials shall be of standard manufacture and will, with all related equipment, appliances, and buildings, be maintained and operated by Processor at Processor’s expense. All testing equipment shall be provided by Processor at Processor’s expense. 6.9. Processing Customer may, at its option and expense, install and operate check meters to monitor Processor’s meters. Such meters shall be for check purposes only and shall not be used in the measurement of Gas for the purposes of this Agreement except as provided for in this Agreement. The installation and operation thereof shall be done entirely by Processing Customer and shall not interfere in any way with the operation of Processor’s meter. The use of a share bar tubing system shall not be permitted. Processing Customer shall also have the right to access, for monitoring purposes, data at Processor’s Receipt Point(s) meters by way of a Supervisory Control and Data Acquisition system, so long as the same does not interfere with Processor’s System. 6.10. Processor’s custody meters shall be tested and calibrated by Processor semi-annually or more often if deemed necessary by Processor. If Processing Customer desires to witness any of the tests provided for herein, Processing Customer shall so advise Processor in writing. If Processing Customer has so advised Processor, then Processor shall give Processing Customer sufficient notice in advance of such tests so that Processing Customer may have its representative present to observe adjustments, if any, which are made. 6.11. When any test shows an error of more than two percent (2%) in measurement, correction shall be made for the period during which the measurement instruments were in error first by correcting the error if the percentage of error is ascertainable by calibration, test or mathematical calculations or second by using the registration of Processing Customer’s check meter, if installed and registering accurately. If neither such method is feasible, correction shall be made by estimating the quantity and quality delivered, based upon deliveries under similar conditions during a period of time when the equipment was registering accurately. If the period during which the measurement was in error cannot be ascertained, correction shall be made for one-half (1/2) of the period elapsed since the last date of test, and the measuring instrument shall be adjusted immediately to measure accurately.