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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
2016 Competitive Retailer Workshop
Opening Remarks
2016 Competitive Retailers Workshop
4
John Hudson
Manager Competitive Retailer Relations
2016 Competitive Retailer Workshop
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
7
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
9
2016 CR Workshop
• Historical Usage Requests
• Manual LOA Requests
• New CRIP Historical Usage / LOA
10
2016 CR Workshop
11
2016 Competitive Retailers Workshop
12
Richard Beasley
CR Relations Account Manager
2016 Competitive Retailer Workshop
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
14
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
15
CenterPoint Energy Historical Usage / LOA
• 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
CenterPoint Energy Historical Usage / LOA
• Click on the HISTORICAL USAGE REQUEST/LOA link on the left side of the screen. The link will bring you to the
page below.
CenterPoint Energy Historical Usage / LOA
• As you fill in the required information, you may see common input errors as shown
below.
CenterPoint Energy Historical Usage / LOA
• Fill out the required information on the LOA request form
• Check the authorization box
• Click Submit
CenterPoint Energy Historical Usage / LOA
• Review and select ESI-IDs
• Check authorization box
• Click Submit
• To cancel without submitting, click cancel
CenterPoint Energy Historical Usage / LOA
• Once confirmed, a “SUBMIT MESSAGE” will verify your LOA request has been made. You will receive an email with
the historical usage data requested.
CenterPoint Energy Historical Usage / LOA
CenterPoint Energy Historical Usage / LOA
CRIP LOA
Live Demonstration
CenterPoint Energy Historical Usage / LOA
Questions?
2016 Competitive Retailers Workshop
25
=
2016 Competitive Retailers Workshop
26
Julienne Sugarek
Bert Sausse, III
CenterPoint Energy Houston Electric
Emergency Operations Plan
April 27, 2016
2016 Competitive Retailer Workshop
Last 5 Years
• 2015 Hurricane Season –
• 11 Storms
• 2014 Hurricane Season –
• 9 Storms
• 2013 Hurricane Season –
• 15 Storms
• 2012 Hurricane Season –
• 19 Storms
• 2011 Hurricane Season –
• 18 Storms
28
2016 Projections
• El Nino
• Trending towards
neutral pattern
• Less Wind Shear in
upper levels
• Easier for storms to
develop
29
Water Temperatures
30
Rainfall & Pressure
31
Analog Years
32
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
35
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
41
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
43
How will CenterPoint Energy
communicate outages and
restoration with the public?
44
Power Alert Service
45
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?
• 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
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
Communications: Initial
outage illustration
48
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
50
Phase II (Starting Day 7): Example restoration forecast by circuit
w/zip code overlay
51
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
52
Questions?
53
Albert Lopez, AMS Manager
Post Storm Recovery
Meter Reading
AMS Data recovery
April 27, 2016
2016 Competitive Retailer Workshop
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.
55
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
56
2016 Competitive Retailers Workshop
57
2016 Competitive Retailers Workshop
58
Charles Whited – Katy & Cypress Service Center Manager
Adrian Moreno – Greenspoint & Spring Branch Service Center Manager
Service Consultant Overview
April 27, 2016
2016 Competitive Retailer Workshop
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
61
Service Consultant
• Answer questions from customers
• Respond to internal and external customers
regarding
• Planned Outages
• Reliability
• Construction & Time Frames
• Customer Issues
62
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.
63
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
64
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
65
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
66
Site Meeting
• Things Needed
• Address & ESI ID#
• Electric Load Analysis
• Electric One Line Diagram
• Site Plan
• Warranty Deed if easements are required
67
Utility Design and Agreements
• Service Outlet Location and Data Statement
• Facilities Extension Agreement
• Start work order preparation and construction
sketch
68
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
69
Construction
• Ensure tree trimming is complete if needed
• All poles staked
• Material secured
• Schedule job with our Operations Department
• Internal or External
70
Energizing the Meter
• Things Needed to Proceed:
• ESI ID#
• Permit
• MVI
• Coordinate Primary Metering Department if necessary
• Accessibility to meter’s location
71
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.
72
2016 Competitive Retailers Workshop
73
Phil Suter
CR Relations Account Manager
CNP Distribution System – “Facilities 101”
April 27, 2016
2016 Competitive Retailer Workshop
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.
76
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
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.
79
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
80
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
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
2016 Competitive Retailers Workshop
87
Rafael Cruz and Synetrick Haynes
Electric Market Operations
CenterPoint Internal System Flow
April 27, 2016
2016 Competitive Retailer Workshop
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
2016 Competitive Retailers Workshop
100
=
2016 Competitive Retailers Workshop
101
John Toubassi
AMS Manager
AMS/IG Highlights & Successes
4/27/16
2016 Competitive Retailer Workshop
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
Meter Data Management
Smart Meter Texas
portal & repository
Advanced Metering System (AMS) Architecture
106
Enterprise Service Bus (ESB)
Data Collection
Engine
(Itron DCE)
Digital
Communications
Backhaul
Meter Data Management
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
2016 Competitive Retailers Workshop
118
Chasta Martin, Director of Rates
Regulatory Update
April 27, 2016
2016 Competitive Retailer Workshop
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
2016 Competitive Retailers Workshop
133
Cheryl Bowman, Energy Efficiency Implementation Manager
David Dzierski, Energy Efficiency Program Manager
Energy Efficiency
April 27, 2016
2016 Competitive Retailer Workshop
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
• Efficiency Connection
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.
• Efficiency Connection
• 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
Manager Competitive Retailer Relations
2016 Competitive Retailer Workshop
Closing Remarks & Wrap Up
2016 Competitive Retailers Workshop
159