Flow

Frontier Energy, North Carolina’s newest gas utility, beganflowing gas in Surry, Wilkes and Yadkin counties. “With more than50 miles of newly installed gas main pressurized, we’re officiallyup and running,” said Andrew Rea, chairman of Frontier Energy. “Injust eight months, we were able to complete the first phase of oursystem and start serving customers.”

Frontier Energy, North Carolina’s newest gas utility, beganflowing gas in Surry, Wilkes and Yadkin counties. “With more than50 miles of newly installed gas main pressurized, we’re officiallyup and running,” said Andrew Rea, chairman of Frontier Energy. “Injust eight months, we were able to complete the first phase of oursystem and start serving customers.”

In another case the FERC is going to have to defend its policyof not requiring pipelines to flow through penalty revenues, theU.S. Court of Appeals ruled Friday in remanding a case involvingNorAm Gas Transmission (No. 97-1607). The 2-1 decision in Amoco v.FERC, with Judge Randolph concurring in part and dissenting inpart, did not object to NorAm’s raising penalty rates, but it doesask for an explanation of why the Commission believes penaltyrevenues will be so insignificant as to warrant no consideration.In the year prior to NorAm’s rate filing the pipeline had collected$1.8 million in penalty revenue. The court noted FERC appeared tobelieve that because penalty rates were raised, the incidence ofpenalties would decrease. But “even if a lesser number of penaltiesare imposed, the increased penalty rate might result in a grossincrease in penalty revenue. Moreover – and this is the keyimponderable – whether a shipper will be willing to incur thepenalty depends on his cost in securing alternative supplies in atight market.”

Pacific Gas & Electric extended a Stage 1 Operational FlowOrder that began Thursday (see Daily GPI, June 11) through today.

Due to excess supply levels threatening system integrity and aconstraint on storage injections, Sonat implemented an OperationalFlow Order Type 6 effective Saturday. The OFO carries tieredpenalties ranging up to $15/dth for shippers with positive dailyimbalances exceeding allocated volumes by 3% or 200 dekatherms. Forthe same reasons as above, Sonat began a production areapoint-specific OFO Type 5 for nine points on its 26-inch Main PassArea Line. A penalty of $15/dth is involved for affected shippersor poolers exceeding scheduled quantities by 4%. Finally, an OFOType 1 (force majeure notice) began Saturday in connection withSonat’s retirement of facilities at the Main Pass 127 platform,which involved shutting in the Main Pass 129 and Main Pass 129Redelivery points. The work, which originally had been scheduled tostart on Friday, was expected to last 24-48 hours.

Northwest said it would not issue an Operational Flow Order fortoday’s gas day even though repairs to Unit #1 at the Snohomish(WA) Compressor Station were continuing Wednesday. The pipelineexpected to complete the work by Wednesday night, but said an OFOstill might be possible should the maintenance continue throughtoday. Northwest credited cool weather and customer cooperation onbalancing with allowing it to meet demand for Sumas/SIPI gas overthe weekend. But with warming weather and continued high demand itis having difficulty meeting Primary Firm nominations without theSnohomish #1 unit

Reacting to frigid weather spreading into the Southeast, Sonatis implementing an Operational Flow Order Type 3 effective todayfor four groups: Birmingham Group, South Main Zone 2, South MainZone 3 and Brunswick Line. The OFO will be extended Wednesday tothe East of Wrens and Savannah Line groups. Due to compressorproblems, Sonat said, the level of interruptible service in the twoSouth Main zones will be less than normal in limitation periods. Inaddition, an OFO Type 22 notice to become effective Wednesday forseven groups was issued by Sonat affiliate South Georgia NaturalGas.

Florida Gas Transmission said Thursday it was experiencing”extremely high” linepack and that Operational Flow Orders would beissued to customers taking less than scheduled volumes. Otheroperational tools such as an Alert Day notice were also beingconsidered, the pipeline said.

As of Friday Sea Robin expected to restore flow Saturday (Feb.21) on its 16-inch West Cameron 580 lateral, pending favorableweather conditions. The force majeure implemented Jan. 27 whenrepairs on a leak began (see Daily GPI, Jan. 29) was to be releasedwhen the lateral was declared in service, Sea Robin said.