ML20082A732

Testimony of Jg Brown on Contention V-3b Re Gas Pipeline Design

ML20082A732
Person / Time
Site:	Limerick
Issue date:	10/10/1983
From:	Jonathan Brown COLUMBIA GAS TRANSMISSION CORP., PECO ENERGY CO., (FORMERLY PHILADELPHIA ELECTRIC
To:
Shared Package
ML20082A708	List: ML20082A704 ML20082A719 ML20082A732 ML20082A739 ML20082A748 ML20082A761 ML20082A779
References
NUDOCS 8311180235
Download: ML20082A732 (8)

Text

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UNITED STATES OF AMERICA NUCLEAR REGULATORY COMMISSION Before the Atomic Safety and Licensing Board In the Matter of )

)

Philadelphia Electric Company ) Docket Nos. 50-352

) 50-353 (Limerick Generating Station, ) -

Units 1 and 2) )

TESTIMONY OF JACK G. BROWN, COLUMBIA GAS TRANSMISSION CORPORATION DIRECTOR OF TRANSMISSION ENGINEERING, RELATED TO CONTENTION V-3b Ql. State your name, title, employer and business address.

4 A1. I am Jack G. Brown, Director, Transmission Engineering, Columbia Gas Transmission Corporation, located at 1700 McCorkle S.E., Charleston, West Virginia 25314.

Q2. Describe your responsibilities in this position.

A2. I have held the position of Director, Transmission Engineering since 1975. As such, I have responsibilities toward the design, construction, operation and maintenance of (1) natural gas pipelines, (2) measuring and regulating stations, and (3) corrosion control of buried and above-ground facilities. In this capacity, I am responsible for setting the goals and objectives for the Manager, Design and Manager, Operations Engineering, who report to me directly with regard to these activities. These responsibilities relate to some 18,000 miles of natural gas pipeline presently in operation.

Q3. Please describe previous work experience and responsibilities related to your present position.

A3. From 1953 to 1966, I was employed by Columbia in various engi-neering positions, both in the field and in the office. Responsibility in 8311180235 B31114 PDR ADOCK 05000352 l T PDR*

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these positions included the technical overseeing of large diameter high pressure pipeline construction, technical directirq related to leak repair and pipeline operation and maintenance, pipelins design and material speci-fication, and corrosion control design and installation.

From 1966 to 1967, I served as Plant Superintendent for the Distribution Department. This position involved the same activities related to low pressure natural gas distribution systems as was previously carried out for high pressure gas transmission systems.

From 1967 to 1970, I became Assistant Superintendent for the Transmission Department. This position involved supervisory responsibility for field pipeline construction and operations and office design engineers.

From 1970 to 1973, I was Manager of Operations Engineering for the Charleston Group. In this capacity I was in charge of the technical aspects of the operation and maintenance of all facilities in a three state operating area. From 1973 to 1975, I was the Senior Corrosion Engineer for all facilities operated by Columbia Gas Transmission which covered a seven state area. -

Q4. Describe your educati.onal background.

A4. In 1953, I received a Bachelor of Engineering degree in Electrical Engineering from Vanderbilt University. In 1963, I received a Bachelor of Science Degree in Business Administration from the University of Charleston.

I am a Registered Professional Engineer (Corrosion Engineering) in California.

QS. Describe your training and experience in the area of pipeline design, construction and operation.

AS. At the outset of my employment with Columbia Gas Transmission, I participated in a 9-month training program which included orientation in the engineering principles applicable to the design, construction, operation, and maintenance of natural gas pipelines. Over the years since that time, I have also participated in several industry sponsored and company sponsored

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-V semirars on the same subjects. Additionally, I received on the job training with regard to these activities as described above. .

, ; In the tenn of my employment by Columbia Gas Transmission since 1953, I have been almost continuously involved in the design, construction, opera-tion and maintenance of high pressure pas pipelines, such as those which have been raised in Contention V-3b. This includes specification and procurement of all necessary materials to meet all applicable code requirements, including government codes. Typically, this involves consideration of the pipeline's pres.sure level and population density in order to calculate the appropriate s

, s stress level of the pipeline materials. Although difficnit to quantify, I ..

would estimate that I have designed and supervised the ronstruction of over 50 different high pressure pipelines, totaling at least 1,000 to 2,000 miles in length.

Q6. Are you familiar with the Columbia Gas Transnission natural gas pipeline,s kos.1278 and 10110?

A6. Yes. These pipelines run generally southwest to northeast through Montgomery County, Pennsylvania.

Q7. Please describe the location of those pipelines in relhtion to the Limerick Generating Station and state the basis of that knowledge.

A7. When Columbia Gas Transmission constructs a natural gas pipeline, infonnation contained in the survey notes of the supervising engineer and as-built deviations are transferred to scaled drawings which show, among other things, the location of the pipelines and position of compressor stations and valves in relation'to physical landmarks the pipeline crosses. Drawings which depict the area in which pipelines Nos.1278 and 10110 pass closest to the Lim'erick Generating Station were provided to Philadephia Electric Company, s .

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1 Q8. How is the pipeline right-of-way at road crossings identified?

A8. An orange plastic marker is placed over the pipeline at the point at which the natural gas pipeline crosses a public road.

Q9. Describe the design and configuration of pipeline Nos.1278 and 10110.

A9. Pipeline No. 1278'is 14 inches in diameter, operates at a normal pumping pressure of 750 psig and a maximum pumping pressure 938 psig. It was constructed in 1949 and is buried a minimum of three feet below grade.

Pipeline No.10110 is 20 inches in diamter, operates at a normal pumping pressure of 1,100 psig end a maximum pumping pressure of 1,200 psig. It was constructed in 1965 and is also buried a minimum of three feet below grade.

Both pipelines share a coninon right-of-way and run parallel 20 to 30 feet apart generally northeast through the area adjacent to the Limerick Plant.

. Each pipeline is constructed of steel commensurate in thickness and grade with its maximum operating pressure. .

Q10. Describe the nearest compressor stations above and below the point at_which the pip'elines pass closest to Limerick.

A10. The Eagle Compressor Station is 9.7 miles south of the point at i

l which the pipelines cross the Schulylkill River. The Easton Compressor Station is 44.4 miles north of this point.

Qli. Describe the manning of Eagle and Easton Compressor Stations.

All. The Eagle Compressor Station is manned at all times. The Easton Compressor Station is manned 4 'nours a day, Monday.through Friday.

Q12. Describe-the protection of this pipeline against corrosion.

A12. These pipeliens are protected from corrosion by an impressed cur-rent cathodic protection system which prevents rusting in the same manner as a battery cathode is protected, i.e., by being a net receiver of current flow.

4 Q13. Describe the provisions which are made to detect leaks in the

< pipeline.

A13. Monthly air patrols survey these pipelines. Since methane gas will kill vegetation in the right-of-way, any substantial leak will result

-in vegetation changes detectable from the air. In addition, a foot patrol covers the right-of-way on a yearly basis. On the average, the pipelines are inspected twice a monI;h for one reason or another, e A , to check on the cathodic protection system and routine right-of-way maintenance (painting fence stiles, checking valve settings, blowing off moisture accumulated in the pipe). Once every three years, Columbia Gas Transmission conducts an instrumentation leak detection survey, utilizing hydrogen flame ionization

("HFI") instrumentation capable of detecting methane leaks of 50 ppm or greater. Finally, farmers, residents, and passers-by furnish leak informa-tion using the phone number listed at road crossings.

Q14. Describe the manner in which leakage would be automatically de-tected and reported. ,

A14. Pressures on these pipelines are electronically monitored by our gas control center at Bethel Park, Pennsylvania. If pressures fall below 425 psi on Line 1278 or 770 psi on Line 10110, alarm set points are triggered at the control center and at Eagle Compressor Station.

At Easton, if the suction pressure falls below 750 psi, alarms are activated at the station and gas control center.

Q15. Describe information available to the operators at the compressor stations which could be utilized to detect and isolate leaks.

A15. The station operators at Eagle aid Easton Compressor Stations have suction and discharge pressures available to them. Alarm set points on the high and low pressures for both lines activate at the stations when

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pressures go out of nonnal operating range.

Upon an alarm, crews would be dispatched to close isolating valves on the effected line to stop the flow of gas.

The valves closest to the Limerick Plant are at Station Number 736+38 for Line 10110 and Station Number 2517+94 for Line 1278. These valves are located approximately 4.3 miles from the Schuylkill River on Line 10110 and are at the river on Line 1278.

Under worse conditions where a line break or large leak occurs in the middle of the night and crews must be called out, it is estimated that valves could be clo;ad and the flow of gas stopped within approximately 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.

Q16. Describe the operating cxperience with this pipeline.

A16. Columbia Gas Transmission has experienced no leak or rupture on either pipeline No.1278 or No.10110 in the history of their operation. Nor have there been any malfunctions or structural failure in either pipeline.

Q17. Describe any ruptures experienced in pipelines of similar design, structure and usage and the impact upon the surrounding environs.

A17. In 1960, a 30-inch natural gas pipeline operating at 936 psig ruptured at a point near Huntington, West Virginia. The pipeline break was a linear fracture of approximately 625 feet. A fire occurred at the moment of rupture, burning trees and the landscape 400 to 500 feet on either side.

No damage occurred beyond 500 feet. In 1982, a 10-inch natural gas pipeline operating at about 980 psi ruptured near Logan, West Virginia. The pipeline completely severed, resulting in an instantaneous fire which burned trees and the landscape 250 to 300 feet on either side.

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Jack G. Brown

_ Professional Qualifications _

Company Affiliation: Columbia Gas Transmission Corporation 1700 McCorkle Avenue, S.E.

Charleston, West Virginia 25314 Born: Paris, Tennessee, March 25, 1930 Education: B.E. in Electrical Engineering - Vanderbilt University,1953 B.S. in Business Administration - University of Charleston, 1963 Employment and Experience:

June,1953 to Present - Columbia Gas Transmission Corporation 1975 to Present - Director of Transmission Engineering.

Responsibilities for design, construction, operation and maintenance of high pressure natural gas transmission lines, measuring and regulating stations, odorization plants and corrosion control facilitias'.

1973 to 1975 - Senior Corro:... Engineer. Responsible for determining policy, methods, t'chniques, and materials for corrosion and leakage control for the corporation in the construction, operation and maintenance of natural gas pro-duction and transmission pipelines and facilities.

1970-1973 - Manager of Operation Engineering. Responsi-bilities included providing standard operation and maintenance procedures and solutions to technical operating problems for all installed facilities for the Charleston Group of Columbia Gas Transmission Corporation.

1967-1970 - Assistant Superintendent for the Transmission Department of United Fuel Gas Company, which was subsequently merged into Columbia Gas Transmission Corporation. Responsi-bilities toward supervising field operation, maintenance and construction activities for pipelines and directing trans-mission pipeline design, including specifying and approving appropriate materials for pipeline construction.

1966-1967 - Plant Superintendent for the Distribution De-partment of United Fuel Gas Company. Responsibilities toward the design, construction, operation and maintenance of low pressure natural gas distribution systems.

1960-1966 - Staff Engineer for the Transmission Department of Unite 7 Fuel Gas Company, Atlantic Seaboard Corporation and Kentucky Gas Transmission (all subsequently merged into Columbia Gas Transmission Corporation). Responsible for

-2 the desigr., material specification and purchasing of suitable materials for the construction, operation and maintenance of high pressure natural gas pipelines and facilities.

1955-1960 - Corrosion Engineer for Transmission Department of above companies. Responsible for the design, installa-tion, operation and maintenance of corrosion control systems for natural gas high pressure pipelines.

1953-1955 - Division Engineer for the Southern Division of l the Transmission Departnent, United Fuel Gas Company.

Responsibilities included construction inspection activities

, on pipeline construction projects, preparing construction cost estimates, providing technical direction for the operation and maintenance of pipeline facilities.

Professional Activities:

Registered Professional Engineer - State of California Member of American Gas Association Chairman, Pipeline Committee, American Gas Association e

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