CENTERPOINT ENERGY’S 2016 COMPETITIVE RETAILER …...CenterPoint Energy Historical Usage / LOA • The CenterPoint Energy LOA is now available on the CRIP! • Key Highlights •

2016 Competitive Retailers Workshop

1

WELCOME TO

CENTERPOINT ENERGY’S

2016 COMPETITIVE RETAILER WORKSHOP

John Hudson

Manager Competitive Retailer Relations

2016 Competitive Retailer Workshop

Welcome and Introductions

Valentine Emesih

Vice President Grid & Market Operations


Opening Remarks


4

John Hudson



CR Survey

Opportunities & Challenges

2016 CR Workshop

• Competitive Retailer Relations – Where we fit in

6

CEHE

Electric

Operations

Grid &

Market

Operations

Distribution

Power

Delivery

Power

Delivery

Solutions

Electric

Market

Operations

2016 CR Workshop

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Electric

Market

Operations

Competitive

Retailer

Relations

Transaction

Management

Field

Operations

Business

Risk

Business

Consulting

2016 CR Workshop

• 2015 Competitive Retailer Survey

• On the whole, positive feedback, but…

• There are some things that we need to fix

8

2016 CR Workshop

• Contact Center

• Electric Customers

• Gas Customers in Multiple Jurisdictions

• Competitive Retailers

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2016 CR Workshop

• Historical Usage Requests

• Manual LOA Requests

• New CRIP Historical Usage / LOA

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2016 CR Workshop

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Richard Beasley

CR Relations Account Manager


CRIP / Usage History (LOA)

& Demo

CenterPoint Energy Historical Usage / LOA

• The CenterPoint Energy LOA is now available on the CRIP!

• Key Highlights • The results are returned via email.

• The data available is the same as the manual LOA process. (Currently non-IDR requests only)

• REP users who are already registered on CRIP will be able to use the LOA without making any changes. [Please note: The assigned CRIP administrator for the REP is responsible for managing (adds/deletes) users on their organization as needed.]

• Non-REPs will need to register an Administrator on CRIP – the first steps are to get a DUNS Number, and fill out a Connectivity Profile. Link for DUNS number: http://www.dnb.com/get-a-duns-number.html

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http://www.dnb.com/get-a-duns-number.html








• The CenterPoint Energy LOA is now available on the CRIP!

• Key Highlights • The results are returned via email.

• The data available is the same as the manual LOA process. (Currently non-IDR requests only)

• REP users who are already registered on CRIP will be able to use the LOA without making any changes. [Please note: The assigned CRIP administrator for the REP is responsible for managing (adds/deletes) users on their organization as needed.]

• Non-REPs will need to register an Administrator on CRIP – the first steps are to get a DUNS Number, and fill out a Connectivity Profile. Link for DUNS number: http://www.dnb.com/get-a-duns-number.html

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• The Homepage includes the Login path to the Non-REP Third Party Historical Request/LOA, “Request Access” and

“Forgot Password” Features.

• CR Relations Web link – http://www.centerpointenergy.com/en-us/business/services/competitive-retailers?sa=ho

• CRIP Link - https://ws.centerpointenergy.com/CNP.CRI.Web.External/Public/Login.aspx

• The Homepage includes the Login path to the Non-REP Third Party Historical Request/LOA, “Request Access” and

“Forgot Password” Features.

• CR Relations Web link – http://www.centerpointenergy.com/en-us/business/services/competitive-retailers?sa=ho

• CRIP Link - https://ws.centerpointenergy.com/CNP.CRI.Web.External/Public/Login.aspx


• Click on the HISTORICAL USAGE REQUEST/LOA link on the left side of the screen. The link will bring you to the

page below.


• As you fill in the required information, you may see common input errors as shown

below.


• Fill out the required information on the LOA request form

• Check the authorization box

• Click Submit


• Review and select ESI-IDs

• Check authorization box

• Click Submit

• To cancel without submitting, click cancel


• Once confirmed, a “SUBMIT MESSAGE” will verify your LOA request has been made. You will receive an email with

the historical usage data requested.



CRIP LOA

Live Demonstration


Questions?


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=


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Julienne Sugarek

Bert Sausse, III

CenterPoint Energy Houston Electric

Emergency Operations Plan

April 27, 2016


Last 5 Years

• 2015 Hurricane Season –

• 11 Storms


• 9 Storms


• 15 Storms


• 19 Storms


• 18 Storms

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2016 Projections

• El Nino

• Trending towards

neutral pattern

• Less Wind Shear in

upper levels

• Easier for storms to

develop

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Water Temperatures

30

Rainfall & Pressure

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Analog Years

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5/22/2006 33

Activating the Emergency Operating

Plan – We follow a preset timeline of

preparation activities

Initial Determination of

Resources Needed

• As the storm approaches, we obtain and evaluate

predictive weather data

• Track of the Storm

• Expected Wind Speeds and Wind Gusts

• Expected Rainfall Amount

• Based on damage predicting algorithms and

historical data, we make an initial determination

of the number of resources that will be required to

repair the damage and restore power to the

distribution system 34

Restoration Resources - Mutual

Assistance with other Utilities

• Mutual Assistance is a nation-wide program of electric utilities willing to safely support other electric utilities during major event on an at cost basis.

• Groups of Utilities have organized by Regions and have formed Regional Mutual Assistance Groups (RMAGs)

• Utilities voluntarily help each other restore electric service after major events, such as ice storms, hurricanes, tornadoes, or floods.

• They provide a rapid, scalable and effective response of labor and equipment

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Acquire Line and Tree Resources

• From Regional Mutual Assistance Groups (RMAGs) • Line Resources

CNP belongs to three RMAGs Southeastern Electric Exchange, Texas & Midwest

These RMAGs provide access to 5,000+ line resources

• From Contractors • Line Resources

Experience and relationship with 70+ line contractors

Provides access to 9,000+ line resources

• Tree Resources Experience and relationship with 20 tree clearance contractors

Provides access to 6,000+ tree resources

Service Area Operations &

Staging Sites

• We have secured at least one primary and one

secondary staging site for each of CNP’s 12 Service

Centers

• Additional primary Staging Sites have been acquired

for some of our Service Centers with large territories

• After a storm, we will open and operate staging sites

in every Service Center that has significant damage

• Logistics personnel manage the Staging Sites

• Electric Operations manage power restoration efforts

out of the Staging Sites 37

Service Area /Staging Site Operation

Plan

38

Baytown

Bellaire

Cypress

Ft. Bend

Galveston

Greenspoint

Humble

Katy

South Houston

Spring Branch

Sugar Land

Houston Raceway Park

Reed Road

Barnett Stadium

Delmar Stadium

Lone Star College - Tomball

Berry Stadium

Fort Bend County Fairgrounds

Wharton County Junior College

Moody Gardens

Galveston Co. Fair & Rodeo

Grounds

H.O. Clarke

Thorne Stadium

Reed Road

Brazoria County Fairgrounds

Lake Jackson Civic Center

Butler Stadium

Humble Civic Center

Don Ford Stadium, New

Caney ISD

Katy Mills Mall

San Felipe

First Baptist Church

Space Center Houston

Deer Park Burk Activity Center

Veteran’s Memorial Stadium (PISD)

Delmar Stadium Second Baptist Church

Fort Bend County Fairgrounds

Stafford Center

Klein Multi-Purpose

Facility

- Primary Sites

- Secondary Sites

Legend:

Gulf Greyhound Park

AMC Theatre Gulf Point 30

Tully Stadium

Staging Site Map

40

Staging Site - Sam Houston Race Track

during Hurricane Ike

We follow a Structured

Restoration Strategy

• Start with the Highest Priority Circuits

• Cut and clear areas of damage for each circuit

• The cut and clear process, when completed, allows us to energize undamaged portions of the circuit; thereby restoring power to a significant number of customers

• We are simultaneously assessing and documenting damage on each circuit

• Damage Assessment documentation is used to create a work plan for each circuit

• Operation Managers will utilize work plans to:

• Plan and assign work to line crews at the staging sites

• Optimize Resource Levels

• Determine additional material needs

• Estimate Restoration Dates for each circuit

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42

Communication Plan

• In the event of any Electric Supply Emergency we provide prompt

notification and continuous appraisal to:

• Public Utility Commission of Texas

• ERCOT

• Department of Energy

• REPs

• Appropriate local utilities

• Local Government officials are kept apprised of restoration status by the

Director of the Service Area they are in

• Government liaison personnel are appointed to the offices of emergency

management at the State of Texas, Harris County, Galveston County,

Brazoria County, Montgomery County and the City of Houston

• We maintain a 24-hour telephone operation service

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How will CenterPoint Energy

communicate outages and

restoration with the public?

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Power Alert Service

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Power Alert Service

If you are a first responder and would like to register for Power Alert Service notifications, please

visit http://CenterpointElectric.com/PowerAlertService

To inquire about registering for Power Alert Service notifications for your business, please

send all inquiries to [email protected]

HOW DO I REGISTER?

http://centerpointelectric.com/PowerAlertservice





mailto:[email protected]



• CenterPoint Energy’s online Customer Outage Tracker displays

current outage locations and estimated time to restore power

• http://CenterPointEnergy.com/OutageTracker

46

Outage Tracker can be used today

http://centerpointenergy.com/OutageTracker

In the event of a severe weather emergency such as a hurricane,

CenterPoint Energy will use Twitter and FaceBook to communicate

• http://twitter.com/CNPalerts

• Facebook.com/CenterPointEnergy

47

Additional communication tools

http://twitter.com/CNPalerts

Communications: Initial

outage illustration

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Phase I (Day 3 thru 7):

Restoration by substation

49

Phase I (Day 3 thru 7): Example restoration forecast by

substation w/zip code overlay

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Phase II (Starting Day 7): Example restoration forecast by circuit

w/zip code overlay

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Always There…For Every Storm

• April 18-21

• Over 244,000

Customers impacted

• Over 125,000 outages

• Mutual Assistance

Called in on April 19

• Power restored to nearly

all customers by April

20th

• Preparing for more

than just Hurricanes

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Questions?

53

Albert Lopez, AMS Manager

Post Storm Recovery

Meter Reading

AMS Data recovery

April 27, 2016


Meter Reading & AMS Data recovery

• A Key Grid and Market Operation EOP Branch Objective

• Clear communications are provided to the electric retail market around current CenterPoint Energy capabilities around service order completion rates, billing reads and settlement data.

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Meter Reading & AMS Data recovery

• Discuss Scenarios For Key Market Processes

• Delivery of settlement (LSE) data to the market

• Execution of AMS service orders

• Delivery of billing reads to the market

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57


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Charles Whited – Katy & Cypress Service Center Manager

Adrian Moreno – Greenspoint & Spring Branch Service Center Manager

Service Consultant Overview

April 27, 2016


Service Consultant

What does a Service Consultant do?

60

Service Consultant

• Single point of contact for our customers

• Contact for multiple departments for various job

functions

• Work closely with city officials to develop

relationships and address their needs

• Create, modify, and manage work orders from the

time they are created until they are closed

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Service Consultant

• Answer questions from customers

• Respond to internal and external customers

regarding

• Planned Outages

• Reliability

• Construction & Time Frames

• Customer Issues

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Work Order Definition

• What triggers our construction to get started?

• Key Milestones leading to the release of a work

order.

• What is a work order?

• A work order is an electronic document created in SAP

so labor and material can be charged to a specific task.

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What Does It Take To Turn On The

Lights?

A Customer can:

• Call CenterPoint Energy’s Customer Service

• Call service center Consultant

• Customer receives a turn down

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What Does It Take To Turn On The

Lights?

Other ways Customers contact CenterPoint Energy:

• Builders

• Electricians

• The customer is the business owners

• Major Under Ground Department

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Key Milestones

• Customer Contact

• Customer Site Meeting

• Utility Design and Agreement Creation

• Agreement Execution and Easements Request if

needed

• Customer Payment

• Construction

• Setting and Energizing the meter

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Site Meeting

• Things Needed

• Address & ESI ID#

• Electric Load Analysis

• Electric One Line Diagram

• Site Plan

• Warranty Deed if easements are required

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Utility Design and Agreements

• Service Outlet Location and Data Statement

• Facilities Extension Agreement

• Start work order preparation and construction

sketch

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Agreements, Easements and

Customer Pay

• Received signed documents and process

payment

• Request easement if required

• Finalize work order and construction sketch

• Secure all necessary permits

• Release to construction

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Construction

• Ensure tree trimming is complete if needed

• All poles staked

• Material secured

• Schedule job with our Operations Department

• Internal or External

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Energizing the Meter

• Things Needed to Proceed:

• ESI ID#

• Permit

• MVI

• Coordinate Primary Metering Department if necessary

• Accessibility to meter’s location

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Summary

• For most projects, this process takes time.

• 10-16 weeks.

• Once a customer starts dirt work, CenterPoint

Energy should be contacted and brought into the

Customer’s project team to ensure Customer’s

Need Date is met.

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73

Phil Suter

CR Relations Account Manager

CNP Distribution System – “Facilities 101”

April 27, 2016


What’s Required to Set That Meter

Anyway?

• Electricity from Generation to Customer

• CNP Service Standards

• Permitting for new meter installations, MVI, etc.

• Common CenterPoint Energy Facilities

• Overhead infrastructure Distribution for Residential

- Single Family - Multi-Family (Apartments / Townhomes)

Distribution for Commercial Area

• Turn-Downs

• Questions

75

How We Deliver Electricity

• Electricity is typically generated in large centralized power plants.

• CNP Facilities take over here

• Power travels long distances via high-voltage transmission lines, which are interconnected in a network or grid.

• From the transmission system, electricity travels to distribution substations. From these substations, distribution lines, operating at lower voltage levels, disperse the power throughout cities and neighborhoods.

• For safety, each distribution line is protected by a circuit breaker in the substation.

• From the distribution line electricity travels through a service transformer entering buildings through either overhead or underground wires that connect to the meter.

• CenterPoint Energy reads this meter each month and reports the information to the retail electric provider. Typically, ownership and responsibility of the wires are transferred from CenterPoint Energy to the customer near the meter (point of service).

• From the point of service, power flows along conductors to the main panel, which contains the main breaker.

• http://www.centerpointenergy.com/en-us/residential/services/electric-utility/how-electricity-gets-to-you?sa=ho#sthash.eXSRrlAg.dpuf.

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http://www.centerpointenergy.com/en-us/residential/services/electric-utility/how-electricity-gets-to-you?sa=hosthash.eXSRrlAg.dpuf














HOW DOES THE SYSTEM WORK?

77

CNP Service Standards - Why Do We

Have Them?

• Experience has shown that certain standard

practices are necessary to ensure every

customer of CenterPoint Energy the best

possible electric service. In compiling this

edition of Service Standards for the guidance

of customers, contractors, electricians,

architects, and engineers, the basic purpose

has been to keep them as simple and non-

restrictive as possible

78

http://www.centerpointenergy.com/en-

us/Services/Pages/electric-service-

standards.aspx?sa=ho&au=res

http://www.centerpointenergy.com/en-us/Documents/Service-Standards.pdf

http://www.centerpointenergy.com/en-us/Documents/Service-Standards.pdf

http://www.centerpointenergy.com/en-us/Services/Pages/electric-service-standards.aspx?sa=ho&au=res







Why is a Permit required for an new

meter installation (MVI)?

• The Customer’s wiring installation

• Should conform to the requirements of the National Electrical Code and the National Electrical Safety Code, State, Municipal requirements in force at the time the installation is made and the Company Service Standards as to Service Outlet Location, Service Drop, Meter Location and height, etc.

• Compliance…is the sole responsibility of the Customer for all Customer wiring and equipment.

• CNP does not inspect Customer wiring and equipment, and the supplying of Electric Service by the Company does not mean that Customer wiring and equipment has been inspected or approved by the Company.

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Examples

PERMITTING ENTITY- PHONE NUMBER - LIFE OF PERMIT - TYPE RES - TYPE GEN

HARRIS COUNTY 713-956-3000 1 year F F

City of Houston 832-394-8847 6 months E/M E

CODE TYPES; E= All new meter Installation and wiring changes

O= For all MVI and Name changes including Mobile Homes

F= All new permanent and/or temporary service.

M= Mobile Homes

Typical Residential Overhead Service

Installations

• OVERHEAD SERVICE

• SERVICE DROP

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Underground Residential Distribution

(URD) Service

81

Temporary Service (T-Saw)

82

TEMPORARY INSTALLATIONS

Where service is required for

construction or other temporary

purposes, the Customer shall

provide a suitable location and

anchorage for the Company's

Service Drop and Meter.

Turn Down Codes

83

TURN DOWN CODES - Revised: 9/13/7A000 WEATHERHEAD (SERVICE OUTLET)A001 Need Meter Loop and Outlet Installed

A002 Need fiber spacer for service entrance conductors

A003 Need weatherhead on conduit above meter base

A004 Fiber wire spacer protector broken in weatherhead

A005 Screws holding head in place broken off or threads stripped

A006 Exceeds 25' above finished grade

A007 Damaged Meter Loop

A008 Needs clamps at Weatherhead

B000 POINT OF ATTACHMENTB001 Too close to window, door or porch, needs to be 3' away

B002 Point of attachment over 3' above roof without guy or bracing

B003 None installed

B004 Drop attachment. Too far from service outlet, should be with 18" of drop

B005 Anchorage not sufficient to support drop cable - 300 lb. pull of service drops

B006 Need penta or creosote treated pole, or a 4" x 6" timber

B007 Temporary meter pole needs bracing to withstand 300 lb.pull of service drops

B008 Meter pole not set deep enough to support drops and withstand 300lbs pull of service drops

B009 Pole not of proper height over driveway. Need 12' vertical clearance above finished grade, over residential driveways

B010 Service attachment needs to be higher for driveway, alleys, roads and streets

B011 Unable to get drop attachment high enough to get clearance from low point of sag in cable service, over sidewalk, porch or platform

B012 Need bracket on the service mast for attaching service rack

B013 Requires secondary rack

B014 Exceeds service drop distance

B015 No Meter Pole

B016 Dose not have 12" clearance from SWBT, Cable TV, etc cables

C000 LINE CONDUITC001 Should not be water pipe fittings

C002 Water pipe not allowed for service outlet conduit

C003 Service outlet conduit not sufficiently clamped to building

C004 Two inch G.I. or I.M.C. or three inch aluminum conduit required for mast head

C005 Electrical junction boxes not sealable type

D000 LINE OF CONDUCTORSD001 Service entrance conductors not identified

D002 Line wire of wrong type insulation

D003 Line wires too short to reach lugs in meter can

D004 Wires from service outlet too short for TDSP to connect drops

D005 No line wires in service outlet

D006 Bare aluminum neutral conductor in meter loop

E000 METER BASEE001 Improperly mounted on pole. Too low or too high

E002 Un-used holes in meter not closed up or covered

E003 No neutral connector in meter base

E004 Meter base improperly mounted. Upside down

E005 Need 125 amp meter base to match customers wire size

E006 Need 200 amp meter base to match customer wire size

E007 Customer wired for current transformer installation. Refer to primary meter man

E008 Foreign type of meter base, TDSP does not

E009 Gang type meter socket base not completely wired

E010 No cover on meter base

E011 Meter base mounted too high above finished grade ground level, should be 5' to 6'

E012 Residential meter socket, need commercial

E013 Meter socket base not level

E014 Ground in meter can

E015 Meter base needs to be replaced

E016 Customer not ready

E017 Faceplate needs Tamper Proof Lid

F000 CUSTOMERS NEUTRAL WIREF001 Must be electronically continuous inside for permanent service socket base

F002 Conductors unidentified in service entrance conductors. Must be white, bare or gray

F003 All 3 phase wires must be identified

F004 Uninsulated aluminum conductor

F005 Bonding conductor for 480 volt, 3 wire service must be a minimum of #6 copper or equivalent and must be insulated

G000 LOAD CONDUITG001 Customer used water pipe nipple going to switch box. Need water tight conduit.

G002 No bushing on conduit from meter base. Weather proff entrance fitting.

H000 CUSTOMERS LOAD CONDUCTORSH001 Exceeds ampacity of meter socket

H002 Has the wrong type of insulation

H003 No wires in load side of meter box

J000 SWITCH BOXJ001 Holes in customers switch box not used or closed. Bare wires and connections exposed.

J002 No ground connector attached to box

J003 Inside mainswitch box mounted outside. Must have water tight connections between meter base and swithc box.

J004 No cover on breaker box. Lighted connections exposed to public

J005 Load wires still energized from backfeed

J006 Neutral connection must be electrically continuous and not fused

J007 Main switch inside premises. Unable to relieve load from loop

J008 Need main breaker if over 6 breakers

K000 GROUNDING ELECTRODE CONDUCTORSK001 Grounding electrode conductor not sized in accordance with table 250-94 of NEC

K001 Grounding electrode conductor not sized in accordance with table 250-94 of NEC

K002 Where used outside, aluminum or copper clad aluminum conductors shall not be installed within 18" of earth

K002 Where used outside, aluminum or copper clad aluminum conductors shall not be installed within 18" of earth

K003 Grounding electrode conductor not securely fastened to the premises below the meter can

K004 No grounding electrode conductor installed

K005 Grounding electrode conductor not attached to ground rod with approved clamp

K006 Has aluminum grounding electrode conductor in direct contact with masonry or earth

K007 Grounding electrode conductor must go from switch bos to ground rod

L000 GROUND CONDUIT OR ARMOREDL001 Not attached to switch box with watertight connector

L002 Not bonded to ground rod

L003 Not attached to switch box

L004 Not secure to building or pole

M000 GROUND CLAMPM001 Unapproved ground clamp

M002 No ground clamp

N000 GROUND RODN001 Must be at least 3/4" galvanized pipe

N002 Steel rod must be 5/8" minimum diameter

N003 Rod or pipe must be 8' deep

P000 PERMITSP001 No permit

P002 Needs city inspection

Q000 CONSTRUCTIONQ001 TDSP construction required

Q002 Customer needs to meet electrician

Q003 Need house or apartment numbers permanently identified

Q004 Corrections not made from previous turndown

Q005 Drops would trespass other's property

Q006 Unable to determine meter base location

Q007 Customer needs to bore

Q008 Service path obstructed

Q009 No equipment access

Q010 Needs grade work

Q011 Customer owned utilities not located

Q012 Customer installed conduit insufficient - Does not meet TDSP specs

R000 UNDERGROUND SERVICE DROPS - (Customer's Responsibility) R001 Service drop not installed

R002 URD drops too short

R003 URD ditch not covered

R004 URD drops not run to the proper point (small notch "V" of the transformer pad)

R005 Wrong type of URD meter can

R006 Unapproved wire for underground

R007 URD service conductors not deep enough

R008 Drops need to be dug within 12" of transformer on pad. Must be clear to open transformer

R009 Underground drops cut in two

R010 T-Saw pole not 4 feet from front of transformer on pad. Must be clear to open transformer

R011 T-Saw pole not 3 feet from rear of transformer

R012 P.V.C. or conduit elbow not deep enough

R013 No P.V.C. or conduit elbow

R014 No line conduit installed

R015 Meter Pole set in easement

S000 MOVE IN'S / MOVE OUTSS001 Inside trouble on customer side

S002 Weatherhead pulled from house or broken

S003 Cannot cut-out at pole, MD, Weatherhead, or remove meter and drops

T000 MISCELLANEOUST001 Business Closed / Customer not home

T002 Meter inside, building locked

T003 Bad dog

T004 High fence, locked gate

T000 MISCELLANEOUS - ContinuedT005 Electrician needs to meet with TDSP meter man

T006 Customer needs to trim trees

T007 No breakers

T008 Customer's facilities under secondary and primary

T009 Meter blocked

T010 Meter in wall

T011 Voided per customer Cannot be used for Disconenct Non-Pay

T012 Re-schedule per customer Cannot be used for Disconnect Non-Pay

T013 Meter damaged

T014 No meter

T015 Muddy road

T016 High water

T017 Customer requested clearance - Unable to do work on date requested

T018 Other Requres explanation in REF03

TX01 Customer has paid receipt - provided proof that bill was paid

TX02 DNP Turned Down - New MVI Pending

TX03 Guard Light Account - DNP Turned Down

U000 UNSAFE CONDITIONSU001 Exposed wires

U002 Jumpers in breaker box

U003 Insects

U004 Excessive debris

U005 Irate Customer

U006 Backfeed on load side jaws

V000 DISCONNECTS FOR NON-PAYV001 Weather Advisory

V002 Life Support Customer

V003 Disconnect Non-Pay: Unable to disconnect standard

V004 Disconnect Non-Pay: Work estimate required, TDSP

V006 Critical Load Premise/Location

Commonly seen Codes

A001 = Need Meter Loop and Outlet

Installed (Customer not ready)

P001 = No permit

P002 = Needs city inspection

Q001 = TDSP construction required

Q003 = Need house or apartment

numbers permanently identified

Q009 = No equipment access

S003 = Cannot cut-out at pole, MD,

Weatherhead, or remove meter and drops

T001 = Business Closed / Customer

not home

T002 = Meter inside, building locked

T004 = High fence, locked gate

T016 = High water

T018 = Other Requires explanation in

REF03 (“contact TDSP for details)

http://www.centerpointenergy.com/PublishingImages

/CNP/Common/SiteAssets/doc/TurnDownCodes.pdf

http://www.centerpointenergy.com/PublishingImages/CNP/Common/SiteAssets/doc/TurnDownCodes.pdf



Commercial Meter Installation

• Typical Overhead service to commercial customer.

• Customer installed “CT” (current transformer) can is used to reduce the current to allow proper metering.

• Single set of CNP secondary drops to single customer.

• Possible issue without access to customer's breakers if CNP needs to disconnect

84

Commercial “Gutter” with multiple

services from single CNP feed

85

Possible Turn- Down? Unable to Relieve Load.

Why? Customer’s locks on their breakers

CNP Distribution System “

Facilities 101”

86


87

Rafael Cruz and Synetrick Haynes

Electric Market Operations

CenterPoint Internal System Flow

April 27, 2016


Objectives

In this presentation we will discuss:

• CenterPoint internal system flow

• NAESB (North American Energy Standards Board)

• EAI (Enterprise Application Integration)

TMH (Transaction Management Hub)

MSO (MDM Service Order Table)

• CIS (Customer Information System)

• ECI ( Electric Commercial & Industrial)

• MDM (Meter Data Management)

• ADMS (Advanced Distribution Management System)

• DCE (Data Collection Engine)

• Service Suite (Field Order Routing System)

89

CNP Internal Systems

90

TMH

CIS MDM

Service Suite (Field Order Routing System)

Order

Success

AMS

Orders

Non

AMS

NAESB

TMH MSO

AMS

Failures

Order

Failure All

Orders

All

Orders

AMS

Orders

DCE

North American Energy Standards

Board (NAESB)

• Used to exchange market transactions

electronically in EDI format

• Receives/Sends positive and negative

acknowledgements (997s) for EDI files

91

Enterprise Application

Integration EAI

• Main purpose is to process AMS orders

• Receives AMS orders from CIS/TMH and sends

orders to MDM for processing

• Sends MDM response to CIS (completions or

failures)

92

Transaction Management Hub

TMH

• Receives inbound transactions from NAESB and

sends to CIS, ECI and EAI-MSO.

• Service Orders (650s)

• Enrollments (814s)

• Receives outbound transactions from ADMS, CIS

and ECI

• Service Orders (650s)

• Enrollments (814s)

• Billing and Usage (867s & 810s)

93

Customer Information System

(CIS)

• System of record for customer information

• Processes order completions and generates completion,

turndown and rejected transactions

• Routes transactions to Service Suite and AMS

• Is the billing engine for residential and small commercial

customers

94

Meter Data Management

MDM

• Receives/stores register reads, interval data, and AMS

meter information. MDM system only handles orders for

AMS meters.

• Receives billing reads request from CIS via MBL (MDM

Billing) and responds with AMS meter readings on the

billing cycle date for use in CIS cycle billing.

• Generates LSE files

• Sends and processes service orders to DCE and sends

replies back to CIS via MSO

95

Data Collection Engine

(DCE)

• Transaction DCE (Data Collection Engine) communicates

to the AMS network

• Does not retain data communication

• Only facilitates communications to the AMS meters and

back to the MDM

96

Service Suite (Field Order

Routing System)

A work load distribution/management system:

• Service Suite system accepts orders from different hosts

• Allows work to be managed by providing a viewable, tractable and reportable workflow of field orders assigned to field personnel

• Receives Non-CDC (Connect/Disconnect) and failed AMS orders requests

• Sends field order completions and un-executables to CIS

• Stores field completion data in Business Objects 97

Summary

You should now understand:

• CenterPoint internal system flow

• NAESB (North American Energy Standards Board)

• EAI (Enterprise Application Integration)

TMH (Transaction Management Hub)

MSO (MDM Service Order Table)

• CIS (Customer Information System)

• ECI ( Electric Commercial & Industrial)

• MDM (Meter Data Management)

• ADMS (Advanced Distribution Management System)

• DCE (Data Collection Engine)

• Service Suite (Field Order Routing System)

98

Questions

99


100

=


101

John Toubassi

AMS Manager

AMS/IG Highlights & Successes

4/27/16


Agenda

• AMS Mission

• AMS Ecosystem in the Texas Electric Market

• Advanced Metering System (AMS) Architecture

• CNP’s Intelligent Grid (IG)

• IG Deployment Scope

• Smart Grid Maturity Model

• AMS Key Successes

• AMS – Current Projects

• AMS – Upcoming Projects

• Q&A

103

AMS Mission

‘Operate and innovate CenterPoint Energy Advanced

Metering Systems to continuously improve

Service to our Customers.’

104

AMS Ecosystem in the Texas Electric Market

105

Consumer

Retail Electric Provider

ERCOT

Ma

rket/

Se

ttle

ment

Tra

nsa

ctio

ns

Market / Settlement

Transactions

Meter / HAN Services

(15-Minute Usage)

Retail Electric

Products & Services

• Pre-pay

• Time of use rates

• Energy analysis tools

Meter / HAN Services

CenterPoint Energy

AMS Network

PHEV

In-Home Display

Thermostat

Smart Appliances

Home Gateway

ZigBee®

Digital meter


Smart Meter Texas

portal & repository

Advanced Metering System (AMS) Architecture

106

Enterprise Service Bus (ESB)

Data Collection

Engine

(Itron DCE)

Digital

Communications

Backhaul


System

(Siemens eMeter MDM)

Wireless Communications

Environment

(GE WiMax)

Outage

Management

System

Communications

AMS OT

Application

Systems

IT Systems

Market Corporate

Analytics Financials

Internal/

External

Customers

Meter Cell

Relay

Take Out Points

(TOPS)

AMS Day in the Life

User Acceptance Environment (EnergyIP 6.2)

Development Environment (EnergyIP 6.2)

Co

re A

MS

Da

ily A

pp

s S

ch

ed

ule

1:00 00:00

(Midnight)

2:00 3:00 4:00 5:00 6:00 7:00 8:00 9:00 10:00 11:00 12:00

(Noon) 13:00 14:00 15:00 16:00 17:00 18:00 19:00 20:00 21:00 22:00 23:00

FlexSync

Interrogations (MDM) 04:00

PM

00:00

AM OW3.7Interrogation

Service Orders (MDM)

DNP Orders

Processed

MVO Orders

Processed

LSE (MDM) VEE Post

Processor

(VEEPP)

DTS On Demand Processor

(LSE File Cut )

Set Release Flag for EAI

AMI Missing Interval Monitor (MDM)

MVI Orders

Processed

OW37ReadRetryClient

(MIM Contingency Reads. Asks

meters for missing interval reads)

07:00

AM

3:00

PM

11:00

PM

AMIMissingIntervalMonitor

(Looks back 7 hours and finds

missing interval reads)

Runs 3x daily

09:00

AM

OCR’s

Process(Switches,

CSAs, and MVI Force

MVO’s

Adhoc

(via Autosys)

Billing (MDM) 7:00 – 8:45

AM

Bill Reads Processor

(Billing Run) every :10 min

MRI’s are released to MDM &

stage demand reset requests

for commercial meters

MDM FlexSync controlled by EAI NRTAutomation

MRE’s are created in EAI for which a NO

READ was received from the MDM

06:00

PM

08:00

AM

Full MRE file built for CIS pickup

07:30

PM

1:30

AM

Siebel Activity Closure

Workflow

(EAI)

FlexSync NRT

(Mon-Sat)

AMI MIM

AMI MIM

OW3.7Interrogation OW3.7Interrogation

10:30

AM

1:00

AM

8:00

AM Settlement

Scheduled

Requests

(SSR1 – 3)

11:00

PM

Adhoc

(via Autosys)

10:00

AM

10:00

AM

08:00

AM PMVI Orders

Processed

AMI MIM

ReRequest

Reprocess

DTS Errors

07:00

AM

DataTransferLoader

(LSE Loader)

FlexSync runs 8:30

PM

11:00

PM

3:00

AM

R/C Orders Processed

(24x7)

07:45

PM

12:00

PM

LIH Orders

Processed

Siebel Mat Views

Fast Refreshed

8:05

PM 9:05

PM 10:05

PM

9:30

PM MIM’s

Released

MIM’s

On Hold

RegisterReadMonitor

(Runs every day in order for the

Missing and Excessive Missing

Read reports to produce data)

AMRFlagSynchronization_IncrSync

(AMR Ready Cutover Report will look

for yesterday’s data)

1:00

AM

5:00

AM

04:00

PM

Service Order end time

except R/C & DNP

(EAI)

FlexSync NRT

(Sun) FlexSync runs 6:00

PM

6:00

AM

1:00

PM

Last LSE data is

delivered to the

market

3:00

AM

11:00

AM

7:00

PM

3:00

PM

Siebel Mat Views

Full Refreshed

8:30

AM 99% LSE data is

delivered to the

market DTL runs

5:30

AM 9:30

AM

Billing (EAI)

2:00

AM

CNP’s Intelligent Grid (IG)

108

Combined with back office computer systems, IG

technology, when fully deployed, will:

Automatically identify the location of power

outages

Isolate faulted sections of the grid

Re-route power from other sources,

essentially ‘healing’ the system.

Field Devices (IGSDs) Communications Advanced Distribution

Management System (ADMS)

Control Center

ADMS – OT/IT Integration

IG Deployment Scope

110

IG Infrastructure

• 31 Substation Upgrades

μP Based Relays & Transformer Monitors

Completed December 2013

• 188 Distribution Circuits (15% of grid)

810 IGSDs

417,845 Customers (+17K, 4.2%)

578 R/C switches or reclosers

Total system automation: 1388 devices

ADMS

• DSCADA - December 2012

• Technical Go Live - November 2014

• Operational Go Live - March 2015

Smart Grid Maturity Model

111

Smart Grid

2.0

Smart Grid

3.0

Smart Grid

1.0

• Smart Metering

• Meter to Market

• SMT Portal

• HAN

• Reporting

• IG – Self Healing Grid

• Analytics – Predictive

• Next Gen Smart Metering platforms

• Grid Edge Intelligence

• DER Integration

• DERMS

• Market Evolution due to decentralized grid

• ADMS

• AMS/IG Integration

• IGSD’s

• PAS

• Analytics - Situational Awareness

Expanded

Energy Resources

Intelligent Grid

Smart Meters

We are here...

AMS Key Successes

• Meter Read Collection

• >99.5% Success

• 260 million read records/day

• ~500K Events/day normally

• ~7M Events/day storms

• Billing

• >140K billing request processed in < 10 min

• Pre-AMS ~2% estimated billings, now .15% estimated billings

• Using alert/alarms, Load side voltage alerts, Tampering alarms, Reverse rotation alerts

Revenue Recoverability

• Service Orders

• >99.5% per day Successful Executions

• Over 11,246,000 processed to date

• ~11K per day. Peak 20K

• LSE/SMT

• Significant improvement of market data delivery

• 99% delivered by 9:30am

112

AMS Key Successes Cont.

• Flexsync

• Asset synchronization CIS System of Record with Meter Data

Management System (MDMS)

Batch to Near Real Time

CIS changes that are currently reflected in the MDM in 1-3 days will now be

reflected in 1-3 hours

Transactional processing improvement will apply evenly to MVI, MVO, Meter

Exchange, Supplier Switch and Meter Installs.

• More timely & efficient market transactions

113

AMS Key Successes – Cont’d

• AMI Outage Integration

• The AMS Outage interfaces enrich our end-to-end outage

detection-to-restoration processes with real-time smart meter

outage data

• Over the past year…30% of outage cases created were from AMI

Customer benefits from automated outage detection & restoration

• Improved zero based estimation

• Power Alert Service (PAS) • Over 9 million (9,143,501) messages sent to customers since 2013

Received by either email/phone/text

Estimation time to restoration

Crew status

Completion time and possible cause

114

AMS - Current Projects

• Outage Event Analyzer/Ping UI 2.0 - (May, 2016)

• Custom application helps to verify the meter state (energized/not energized)

• Enhances current search and ping options and also provides a graphical (map) view of outages

• MDM 7.7 Upgrade (July, 2016)

• DCE 3.9 Firmware Upgrade (Sept., 2016)

• Distribution Transformer Monitor Piloting

• Revenue Protection

• Outage detection – Major underground/Industrial metering

• Operations Optimization – Next Gen Monitoring

115

AMS – Upcoming Projects

116

• MDM Next Generation

• Itron Head End Upgrade

• Voltage Monitoring

• DER Integration Solutions Planning

• DERMS – EIC Pilot

Q & A

117


118

Chasta Martin, Director of Rates

Regulatory Update

April 27, 2016


REGULATORY

UPDATE

APRIL 2016

CNP Regulatory Update

•Topics:

• Filings

• Pending Issues

• Potential Market Developments

1

Filings

• Annual Filings

True-Up Schedules

Tariff Riders

Results in changes to various TDSP charges

• Semi-Annual Filings

TCRF

TCRF Semi-Annual Report

• Quarterly Filings

Performance Measures

2

Annual Filings

• True-Up Schedules

Recovery of costs through issuance of bonds rather than base rates Requires enough annual revenue to cover annual bond obligations

– Flow through from customer to bond-holders

Apply to all applicable rate classes

Last for life of the bonds

Filed 30/90 days prior to effective date

• Riders

Charges to pay for Commission approved cost recovery not in T&D base rates Applies to appropriate rate classes

Filing dates for updates dictated on a case by case basis

Trend - effective 45 days after Final Order for REP notification

3

Tariff – Schedules & Riders

• Bond Issuance Related:

Schedule TC2 – Transition Charges – expires Dec 2019

Schedule TC3 – Transition Charges – expires Feb 2020

Schedule SRC – System Restoration Charges – expires Nov 2022

Schedule TC5 – Transition Charges – expires Jan 2025

• Rider SBF – System Benefit Fund – currently $0

• Rider NDC – Nuclear Decommissioning Charges

• Rider TCRF – Transmission Cost Recovery Factor – updates in Mar and Sept

• Rider AMS – Surcharge for Advanced Metering System

Expired for residential customers

Expires 2016-2017 for Non-Residential Customers

• Rider EECRF – Energy Efficiency Cost Recovery Factor – updates annually

• Rider ADFITC – Accum. Deferred Fed. Income Tax Credit – expires Nov 2022

• Rider DCRF – Distribution Cost Recovery Factor

• Municipal Account Franchise Credit

4

Annual Filings – True-Ups

• Transition/Storm Recovery Charges

PUC

Docket

Charge Amount Begin Length Annual

Update 3

30485 Transition Charge II

(TC2) 1

$ 1.85 B Dec 2005 14 Years Dec 1

34448 Transition Charge III

(TC3) 1

$ 488.5 M Feb 2008 12 Years Feb 1

37200 Storm Restoration

Charge (SRC) 2

$ 664.9 M Nov 2009 13 Years Oct 15

39809 Transition Charge V

(TC5)

$ 1.695 B Jan 2012 13 Years Dec 15

Notes: (1) ADFIT benefit within amount (2) ADFIT benefit separate charge – updated same time (3) Filed 30/90 days prior

5

Annual Filings - Riders

Energy Efficiency Cost Recovery Factor (EECRF)

Cost associated with Energy Efficiency programs

Forecasted Program Costs / Earned Bonus / Previous Under/Over Recovery

Annual filing June 1st for March 1st effective date of the following year

Applies to all customers except Transmission Voltage – Industrial

7

Semi-Annual Filings - Riders

• Transmission Cost Recovery Factor (TCRF)

• Cost associated with DSP payments to all TSPs not in base rates

• Matches Expenses to Revenues – True-up - no under/over recovery

• Applies to all rate classes except lighting

• Updated twice per year (3/1 & 9/1)

• Filed 3 months in advance of effective date (12/1 & 6/1)

TCRF

Update filed

(Dec 1)

TCRF Rates

Effective

(Mar 1)

TCRF Update filed to

Incorporate Changes in

Rates (Jun 1)

Lag Period Expenses Recovered By Rule Formula

PUCT Approves TSPs Transmission

Cost/Rate Updates

CNP DSP Begins Paying TSP Updated Rates

TCRF Rates

Effective

(Sep 1)

6

Semi-Annual Filings - Reports

•TCRF Semi-Annual Report

• Required by Subst. R. §25.193(e)

• Includes information on:

Estimated monthly TCRF cost

Actual cumulative TCRF cost

Amount of TCOS in base rates

TCRF revenues

Calculation of the TCRF

Adjustment for over/under collections

• Filing is duplicative of information found in TCRF

application filings 8

Quarterly Filings – Performance

Measures

• Filed 45 days after quarter ends

• 5 measures

A-1: Number of Customers and MWH sales by REP

A-2: Number of Active REPs

B-1: Customer Enrollment Success Rate by REP

B-2: Meter Read Transaction Success Rate by REP

C: Field Performance by REP

9 40

50

60

70

80

90

100

110

120

Number of REPs

Quarterly Filings – Performance

Measures

• CNP Overall Field Performance Metrics

Metric Standard 4th Qtr.- 2015

Achievement Standard Move In 2 Business Days 99.93%

Priority Move In Same Business Day if Requested by 5 pm

99.89%

Move Out 2 Business Days 99.56%

Disconnect for Non-Payment 3 Business Days 99.92%

Standard Reconnect after DNP

Same Business Day if Requested by 2 pm

100%

Same Day Reconnect after DNP

Same Business Day if Requested by 5 pm

100%

10

Pending Issues

• AMS Surcharge

Expired for Residential customers in May 2015

Expires 2016-2017 for Non-Residential customers (Exp.

2/28/2017 for Secondary Service< 10kVa, Exp. 1/31/2016 for

Secondary Service>10kVa, Exp. 7/31/2016 for Primary

Service)

• DCRF Tariff & Rate Filing Package

Recovery of Distribution Invested Capital

Filed April 4th for September 1 implementation-Docket No.

45747

11

Potential Market Developments (Rulemaking)

PUC

Docket

Topic Legislature Proposed Changes/Issues

45134 Alternative Rate

Mechanism

SB 774 •Potential change in alternative ratemaking

mechanisms (2019)

42786 Advanced

Metering Web

Portals

§ 39.151 •Change in how costs for portals will be

recovered among utilities

•Additional functionality added

42532 Distributed

Generation

§ 39.916 •Who can enter into interconnection

agreement's (retail customer or 3rd DGO)

•Change in MW cap in the DG rule

13


133

Cheryl Bowman, Energy Efficiency Implementation Manager

David Dzierski, Energy Efficiency Program Manager

Energy Efficiency

April 27, 2016


Benefits of Energy Efficiency

• Assist distribution customers

• Reduce load on grid

• Assist your customers to be more energy efficient

• It helps us both look good!!

135

CenterPoint Energy’s Role

136

CenterPoint Programs

Administration

Inspection

Incentives

Commercial Facility

Third Party Contractor

Residential Home

MW Goal Performance

• Historical Achievements

137

42.7

41.3

51.3

68.1

76.1

121.0

110.2

271.7

195.1

159.2

168.6

0 50 100 150 200 250 300

2005

2006

2007

2008

2009

2010

2011

2012

2013

2014

2015

Measure Eligibility

• Produces measureable peak demand and / or

energy savings

• Peak demand is defined as June 1 through

September 30, Monday – Friday 1PM to 7PM

• Exceeds minimum energy efficiency standards

(code)

• Payments made to program sponsor, not resident

138

Customer Classes

139

Commercial Residential Hard-to-Reach

Commercial Programs

140

Commercial Programs

9

Commercial SOP

• Offers incentives to energy efficiency service providers who install qualified energy efficiency projects in new or existing commercial and industrial facilities.

• Chiller replacement

• Packaged cooling unit replacement

• Lighting retrofits

• Lamp and ballast

• Motor efficiency measures

• Window film applications

• Roofing applications

141

Retro - Commissioning

• Promotes the optimization of existing commercial and

industrial buildings by evaluating facility systems and

implementing low-cost/no-cost measures.

• Provides an engineering evaluation, similar to an

ASHRAE level II audit, at no cost. (assumes they will

implement identified measures)

142

Healthcare Energy Efficiency

Program

• Provides small hospitals, assisted living centers,

clinics and labs with technical assistance

• Energy assessments

• Recommendations for operational improvements

• Savings Calculations

• Assistance with measurement and verification

143

Data Centers Energy Efficiency

Program

• DCEEP is offered at no cost to the customer. It is

designed to encourage data center energy

efficiency improvement that includes:

• Technical assistance that identifies energy-saving

projects, and provides recommendations on the

industry’s latest best practices

• Financial incentives that reduce payback period of your

investment by earning cash payments based on verified

peak demand reduction and annual energy savings

• Savings verification to prove energy savings after

projects are completed

144

Smart Pools – Pool Pump Program

• Provides incentives to pool

contractors who install

variable speed pool

pumps on in-ground

commercial and residential

swimming pools.

145

Residential Programs

146

Residential & Hard-To-Reach Programs

11

Residential & SC SOP

• The Residential and Small Commercial Standard

Offer Program provides incentives to third party

contractors for the installation of energy efficiency

retrofit projects in residences

• Ceiling insulation

• Installation of energy efficient windows

• Replacement of existing air conditioning system with a

high efficiency system

147

Programs for Retail Electric

Providers

• Residential Demand Response

• Cool Saver

• Commercial

• Residential

• Low-Income

• Efficiency Connection

148

Residential DR BYOD

• A Residential demand response program for third

party participants who have customers with

programmable thermostats

• REP’s

• Cable TV companies

• Aggregators

• Alarm companies

• Other

149

2016 REP Program

• 2016 Budget $2,500,000

• A/C Tune-up


150

REP Program

• REP CoolSaver A/C Tune-Up Program

• Offers a free A/C tune-up marketed by participating

REP’s for residential, income qualified and commercial

customers.


• Provides the opportunity for customers to purchase

LED bulbs at a reduced price utilizing an internet

marketplace.

151

REP MTP - 2015

• Coolsaver – Residential

• 6,804 Tune Ups, $1,032,600

• Coolsaver – Commercial

• 1,284 Tune Ups, $192,600

• Coolsaver – Income Qualified

• 83 Tune Ups, $12,450

• Efficiency Connection LED

• 15,392 LED Bulbs, $610,653

152

www.techniart.com

153

Across the State

154

Web site : www.texasefficinecy.com

Service Area Map

155

Program Information

• Web site: www.centerpointefficiency.com

• Contact: Cheryl Bowman 713-207-5631

David Dzierski 713-207-3341

156

Questions

157

John Hudson



Closing Remarks & Wrap Up


159