CenterPoint Energy 2015 Annual Report Download - page 14
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Please find page 14 of the 2015 CenterPoint Energy annual report below. You can navigate through the pages in the report by either clicking on the pages listed below, or by using the keyword search tool below to find specific information within the annual report.AllREPsinCenterPointHouston’sserviceareapaythesame ratesand otherchargesfortransmissionanddistributionservices.Thisregulateddeliverycharge
includes the transmission and distribution rate (which includes municipal franchise fees), a distribution recovery mechanism for recovery of incremental
distribution-investedcapitalabovethatwhichisalreadyreflectedinthebasedistributionrate,anucleardecommissioningchargeassociatedwithdecommissioning
theSouthTexasnucleargeneratingfacility,anenergyefficiencycostrecoverycharge,asurchargerelatedtotheimplementationofAMSandchargesassociated
withsecuritization of regulatoryassets,stranded costs andrestoration costs relating toHurricane Ike. Transmissionratescharged todistributioncompaniesare
basedonamountsofenergytransmittedunder“postagestamp”ratesthatdonotvarywiththedistancetheenergyisbeingtransmitted.Alldistributioncompanies
inERCOTpayCenterPointHoustonthesameratesandotherchargesfortransmissionservices.
ForadiscussionofcertainofCenterPointHouston’songoingregulatoryproceedings,see“Management’sDiscussionandAnalysisofFinancialConditionand
ResultsofOperations—LiquidityandCapitalResources—RegulatoryMatters—CenterPointHouston”inItem7ofPartIIofthisreport,whichdiscussionis
incorporatedhereinbyreference.
State and Local Regulation – Natural Gas Distribution
InalmostallcommunitiesinwhichNGDprovidesnaturalgasdistributionservices,itoperatesunderfranchises,certificatesorlicensesobtainedfromstate
andlocalauthorities.Theoriginaltermsofthefranchises,withvariousexpirationdates,typicallyrangefrom10to30years,althoughfranchisesinArkansasare
perpetual.NGDexpectstobeabletorenewexpiringfranchises.Inmostcases,franchisestoprovidenaturalgasutilityservicesarenotexclusive.
Substantially all of NGD is subject to cost-of-service rate regulation by the relevant state public utility commissions and, in Texas, by the Railroad
CommissionofTexas(RailroadCommission)andthosemunicipalitiesservedbyNGDthathaveretainedoriginaljurisdiction.Incertainofitsjurisdictions,NGD
hasineffectannualrateadjustmentmechanismsthatprovideforchangesinratesdependentuponcertainchangesininvestedcapital,earnedreturnsonequityor
actualmarginsrealized.
Foradiscussion of certain of NGD’s ongoing regulatory proceedings, see “Management’s Discussion andAnalysisofFinancialConditionand Results of
Operations—LiquidityandCapitalResources—RegulatoryMatters—CERC”inItem7ofPartIIofthisreport,whichdiscussionisincorporatedhereinby
reference.
Department of Transportation
InDecember2006,CongressenactedthePipelineInspection,Protection,EnforcementandSafetyActof2006(2006Act),whichreauthorizedtheprograms
adoptedunderthePipelineSafetyImprovementActof2002(2002Act).Theseprogramsincludedseveralrequirementsrelatedtoensuringpipelinesafety,anda
requirementtoassesstheintegrityofpipelinetransmissionfacilitiesinareasofhighpopulationconcentration.
Pursuant to the 2006 Act, the Pipeline and Hazardous Materials Safety Administration (PHMSA) at the Department of Transportation (DOT) issued
regulations, effective February 12, 2010, requiring operators of gas distribution pipelines to develop and implement integrity management programs similar to
thoserequiredfor gas transmission pipelines, but tailored to reflect thedifferencesindistributionpipelines.Operatorsof natural gas distribution systems were
requiredtowriteandimplementtheirintegritymanagementprogramsbyAugust2,2011.Ournaturalgasdistributionsystemsmetthisdeadline.
Pursuanttothe2002Actandthe2006Act,PHMSAhasadoptedanumberofrulesconcerning,amongotherthings,distinguishingbetweengatheringlines
and transmission facilities, requiring certain designand construction features in new andreplaced lines to reduce corrosion and requiringpipeline operators to
amendexistingwrittenoperationsandmaintenanceproceduresandoperatorqualificationprograms.PHMSAalsoupdateditsreportingrequirementsfornatural
gaspipelineseffectiveJanuary1,2011.
InDecember2011,CongresspassedthePipelineSafety,RegulatoryCertainty,andJobCreationActof2011(2011Act).Thisactincreasesthemaximumcivil
penaltiesforpipelinesafetyadministrativeenforcementactions;requirestheDOTtostudyandreportontheexpansionofintegritymanagementrequirementsand
thesufficiencyofexistinggatheringlineregulationstoensuresafety;requirespipelineoperatorstoverifytheirrecordsonmaximumallowableoperatingpressure;
andimposesnewemergencyresponseandincidentnotificationrequirements.
We anticipate that compliance with PHMSA’s regulations, performance of the remediation activities by CERC’s natural gas distribution companies and
intrastatepipelinesandverificationofrecordsonmaximumallowableoperatingpressurewillrequireincreasesinbothcapitalexpendituresandoperatingcosts.
Thelevelofexpenditureswilldependuponseveralfactors,includingage,locationandoperatingpressuresofthefacilities.Inparticular,thecostofcompliance
withDOT’sintegritymanagementrules
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