PSWG Group 4. 
Section 2 Draft Writeup
A. Safety issues (customer life support, public, etc.)
1.	Electrical Hazards:
•	Exposed wiring, damaged sockets (loose or burnt wiring or jaws), auto-bypass devices (load jaws still hot when meter removed), loose or missing screws (i.e., in bypass area), missing panels, loose or broken service insulators, service wires in bad condition/order, missing meter, improper grounding conditions, fused neutral conductor of a 2 wire or 3 wire single phase service, defective service switch/disconnect, new installations which fail to conform with the UDC’s electric service requirements, etc.
•	UDC installed voltage arrestors: Should be remove or cut in clear if present unless UDC requests to keep arrestors in place.

2.	Physical Hazards
•	Tripping hazards (slippery or uneven surfaces), debris or materials stored in the working space, overhead hazards (stored materials or workers above meters).
•	Environmental hazards: Chemical, caustic, hearing, biological, etc. 
•	Inadequate or unsafe access
•	Meter Mounting: loose meter mounting, undue vibration, inability to securely seal metering, unleveled meter.

Implementation of MSP certification (joint meets)
B. Meter security and accessibility
Infractions and Evidence of Tampering/Energy Diversion
a) 	Meter Installation
•	Awareness of significant connected loads compared to a customer's monthly energy consumption.
•	Irregularities in the service conductor's insulation ("skinned" insulation, newly-taped sections of conductors, burned or pitted service conductors, etc.)
•	Unauthorized connection in overhead service entrance, on line side of metering transformers, or in unsealed underground pull section.
•	Unauthorized seals, and unsealed or improperly sealed conditions on gutters, wire ways, pull sections, test block compartments, test switch covers, and meter sealing rings.
•	Suspicious wiring.
•	Jumpers across current leads at bottom of test switch unsealed.
•	Meter Coil Jumpered - Check and correct if the neutral service wire is found connected through the series coil of the meter and there are grounds on the load circuits that act as a jumper.
•	Lock Fuse Jumpered - Check for lock fuse jumper and perform a regular meter test.  Jumper will be left as found, and this condition will be reported on the test report.
•	Blown (or loosened) fuse in one leg of a 3-wire old sequence service.
•	Wiring in unsealed raceway or pull box.
•	Rate infractions in the meter program/register.
b)	Meter Cover: An unusually clean cover, small holes in the cover, burn marks on or near the cover, visible fingerprints inside the cover, etc.
c)	KWH Register: KWH dial pointer alignment, register mesh and register gears
d)	Meter Disk: Disk alignment to magnets, irregularity of disk rotation, foreign objects or materials on disk/bearing, scratches or wear marks on the disk
e)	Test Blocks: Damaged wiring between test block and meter, unusual marks, scratches or burns on test blocks, defective test blocks, etc.
f)	Meter Base: Unusual marks and mushroomed screw slots on potential links; broken meter seals; unusual wear or scratches, burn or pit marks on meter stabs/blades/terminals; etc.
g)	Meter Socket: Unusual wear or scratches, burnt or pit marks, irregular meter socket voltages, circuit bypass jumper, etc.
h)	Hidden "Service Riser" Taps and Unmetered Circuits Utilizing Relay Devices: Unusual noises that could indicate a relay opening when the meter is removed from the socket.
4. 	Clock Load : Calculate and record customer's load at time of arrival.

C.  Site verification
DA Metering Verification:
•	Check for proof of DA meter certification or meter types that had been installed prior to 1/1/98 and grandfathered.
•	Verify for correct billing information (records versus meters) including billing constant, meter number, accuracy test results, customer information, etc.
•	Verify for correct meter and service (voltage, form, etc.)

	6.	DA Communication Verification:
•	Verify for correct phone or other communication devices and connections if remote read
•	Verify for successful communication handshakes and data retrieval if remote read (This can be done by another person at a remote location, and data accuracy is not verified at this time).
•	Verify for successful meter reading if manual read.

7.	Customer premises: Unsafe conditions of customer-owned stairs, railings, platforms, etc.

8.	Vermins: Watch out for insects, snakes, and rodents when opening doors or removing panels.	

Transformer Rated Meter Sites

In addition to the inspections described in the All Meter Sites section above, visually inspect all Transformer Rated Meter sites for the following conditions:

1.	Billing Constant: Compare between records versus sites (CT’s/PT’s ratios)
2.	Improper Wiring: Shorted current by-pass links, reverse current secondary wired, unmatched voltage and current circuits, pinched or rubbed secondary wires near panel hinges.

C.	Pole Mounted Meter Sites

In addition to the inspections described in the All Meter Sites section above, visually inspect pole-mounted meter sites for the following conditions:

1.	Cutouts: Open cutouts, blown triple link fuses.
2.	Grounding: Ground conductors and connections shall not be broken at any point between the meter enclosure and the ground rod.	

D.	PAD Mounted Meter Sites

In addition to the inspections described in the All Meter Sites section above, visually inspect PAD-mounted meter sites for the following conditions:

1.	Condition of Primary load bread elbows
 Grounding

•	PG&E, SCE, and SDG&E have three phase services with ground connection on one of the phases.  In situations where A, B, or C, phase is not grounded and there is a voltage reading at or near zero volts on any phase and reading above zero volts on any other phases, report the hazard to the UDC immediately for emergency corrections and contact the customer or customer’s representative to inform them of the hazardous conditions.  If it is unclear whether a phase is intentionally grounded, contact the local UDC to clarify the configuration of the service.  Additionally, take an extreme caution on primary (above 600 V), 480 V phase to phase or 277 V phase to ground service.

D.  Meter Installation
•	procedural requirements including customer interface
Testing and calibration
pre-installation
Task #1: Voltage Test

On all services, measure the secondary voltage, with an approved volt meter,  between the line phases and line to ground even if it is an ungrounded service and record all voltage readings on the test tag.  All nominal voltages have an allowable tolerance of 5%.

A.  Secondary Distribution Voltages: 	Normal rating of 120 Vac.

Table 1: Nominal Voltages and allowable limits on Secondary
Nominal Voltage (Volt) | Maximum (Volt) | Minimum (Volt)
120 | 126 | 114
208 | 218 | 198
240 | 252 | 228
277 | 291 | 263
480 | 504 | 456

Table 2: Service Voltages and allowable limits on Secondary
Service Voltage (Volt) | Measured Voltage (Volt) | Maximum (Volt) | Minimum (Volt)

120/240V 3w 1ø

120V Phase to Ground
240V Phase to Phase

126
252

114
228

120/208V 3w 1ø

120V Phase to Ground
208V Phase to Phase

126
218

114
198

120/208V 4w 3ø

120V Phase to Ground
208V Phase to Phase

126
218

114
198

120/240V 4w 3ø

120V Phase to Ground
208V Phase to Ground
240V Phase to Phase

126
218
252

114
198 
228

277/480V 4w 3ø

277V Phase to Ground
480V Phase to Phase

291
504

263
456

240V 3w 3ø | 240V Phase to Phase | 252 | 228
480V 3w 3ø | 480V Phase to Phase | 504 | 456

E.  upon installation
F.	
post-installation, in service

Certification testing:
1) 	Use ISO certification and 4 additional tests to cover communication testing and sun-light affect testing, or
2) 	Use CPUC’s decision D97-12-048, or
3) 	Use Appendix B of Bob Lane’s document.
Enforcement Process:
•	Manufacturer issues a certification testing document which is verified and approved by an ESP(MSP)/UDC (user of meters), and
•	Manufacturer sends a copy of its certification testing document to the CPUC for access to public review or posting on a web site.

G.  Maintenance
Task #1: Meter Testing Criteria  (testing criteria table: see attachment #1)

Task #2: Light Load & Full Load Test  

Light load is 10% of name plate or test Amp rating, and full load is 100% of name plate or test Amp rating.  The light and full load test is performed at 100% power factor to verify the accuracy of the meter by comparing its test results with a Standard Meter of known traceable accuracy.   

•	No Load or Creep Test (for mechanical and hybrid meters only):
Test meters will be energized with no connected load, and the disk observed for rotation.  A minimum amount of creep is acceptable if the rotation stops when an anti-creep hole reaches the meter stator.

•	Accuracy test:
Single phase and polyphase meters are to be tested with potential coils connected in parallel and the current coils connected in series.  The minimum duration of the test will be 1 disk revolution for light load and 10 disk revolutions for full load.  For solid state meters, calculated pseudo revolutions will be used.

•	Adjustments:
Meters found within the limits required by the local UDC need not be adjusted.

•	Reporting:
Correction factors for light load and full load tests will be recorded as the meter accuracy results. 
Example: A 0.5% fast and slow meter:
				Correction Factor		Accuracy
Fast			0.995				+0.5%
Slow			1.005				-0.5%.

•	UDC Notification
Meter Agent must notify the UDC’s upon finding a defective meter that affects billing.

•	Single Phase Services:
This task is not required for single phase services.

	Task #3: Demand Test

This test procedure can be done on site or at the responsible agency’s testing facility.

A.  Mechanical Demand Meters

Test for the accuracy of the demand registers by checking the marked register ratio and time interval as follows:

•	Advancing Mechanism:
Visually inspect the pusher arm and gears for worn out parts.   

•	Clutch:
Check that the pusher arm returns to zero at the end of interval when the clutch releases it.  Verify that this is a smooth operation and the pusher arm it returns to the stop position.

•	Timing Motor:
Check that the timing motor is operating.  If the motor is not operating the demand reading will most likely be off scale.

•	Time Interval and Demand Test:
Test the time interval to insure that it is as marked on the register name plate by timing the motor gear and clocking an interval, or performing a demand test.  The demand test is performed by minimally applying full load current for 125 disk revolutions on 15 minute demand meters and for 250 disk revolutions on 30 minute demand meters.

•	Demand Mechanism:
Check that the demand reset returns the pointer to zero on a reset action and that the pointer will advance to full scale. 

•	Reporting:
Correction factor for the demand test will be recorded as the meter accuracy result. 
Example: A 0.5% fast and slow meter:
				Correction Factor		Accuracy
Fast			0.995				+0.5%
Slow			1.005				-0.5%.
. 

 Solid State Meters and Electronic Registers

Below is a procedure for a demand test on a solid state meter or an electronic register. 

1.	Place the meter register in the TEST MODE.
2.	Press reset button to clear all test registers and start new demand interval.
3.	Apply full load current for 25 disk revolutions as a minimum.
4.	Scroll the register display to show present kW demand.  If the kW value is in pulses, calculate the actual kW value. 
5.	 Calculate and record the correction factor by comparing the meter kW value with the kW in the test standard.
6.	 Return the meter to the NORMAL MODE.

Task #4: Register Verification

A.  Mechanical Register
Visually inspect and verify that the register is correct for the watt-hour meter, and  that the register constant, gear ratio, and register ratio are correct for the register.

•	Gear mechanism:
Check that the gears are clean, and check the proper engagement between gears and between the first gear and the disk shaft.   

•	Mechanical register:	
Check that the register ratio is the same as marked.  The register ratio (Rr) is determined by counting the number of revolutions required of the first gear to cause the first dial pointer to make one complete revolution.  

B.  Electronic register 
Because electronic registers are different for each type and manufacturer, manufacturer’s manual should be referred to for specific procedures for these registers.   Below is a typical procedure for verifying electronic registers after they are programmed with proper parameters: 

•	Check all numerical segments and identifiers on the meter display.  
•	Check the meter is scrolling properly through all registers.   
•	Check the function of the registers by disconnecting and then restoring power on the meter.  The meter should resume normal display operations and reading after this power outage.
•	Verify the programming parameters are correct.
•	Check the register memory and load profile data memory to verify that data is being stored.

Task #5: Phase Angle Test

Check for correct wiring on a reactive metering site and proper phase shift on each phase circuit.  If the rotation is not correct, the site will have a leading Power Factor.  When the rotation is correct, the site will have a lagging Power Factor.

•	Reactiformer voltage:
Measure the voltage on the top of the reactiformer to insure the proper voltage is applied to the potential coil in the RKVAh meter.  If the voltage is not correct, the following are possibilities of errors: 
1) Factory incorrect wiring on the reactiformer 
2) Incorrect voltage for the applied service
3) Incorrect wiring at the site during installation.

•	Power Factor Calculation:
Calculate the load on the KWH and the RKVAH meters and the power factor for the site.  This power factor is used as a cross check for the measured phase angle. 

•	Current Measurement:
Measure each phase current and record it accordingly.

•	Phase Angle Measurement:
Use phase angle meter to measure each phase angle and record it accordingly.

•	Phase Angle Plot:
After measuring all voltages, currents and phase angles, plot a phase angle test and cross check with the calculated power factor.

Task #6: Separate Element Test

Check individual elements of transformer rated and self contained meters for proper disk rotation or registration by performing the following:

•	Testing
Energize with the appropriate phase potentials and place current on individual elements, and check for forward rotation or positive registration

•	Correct phasing
Check that the proper potential coil and current coil are wired correctly in the meter.  If the meter is installed correctly on the socket, the meter disk will rotate forward.

•	No forward rotation
If an element has no rotation check the following:
•	Open potential coil (Check with a magnet or an ohmmeter.)
•	No load current.  

•	Note
	Phase angle relationships may cause slight reverse rotation in cases where there is a poor power factor.  If any substantial reverse rotation is observed, the service should be checked for unmetered loads.  This will only occur on three wire three phase metered service sites.

•	Single Phase Services:
This task is not required for single phase services.

H.  Scheduled 

I.  Troubleshooting and repair

J.  PT/CT secondary wiring and maintenance requirements

Primary Distribution and Transmission Voltages: These voltages have secondary voltage rating of 115 Vac or 120 Vac.   The voltage transformer primary may be connected either wye or delta.

Table 3: Primary and Transmission Voltages with their secondary voltages and ratios

Possible System 
L-L Voltage (Volt)

VT Primary Voltage (Volt)

Secondary Rating (Volt)

Ratio

2,400 or 4,200 | 2,400 | 120 | 20:1
4,200 or 7,200 | 4,200 | 120 | 35:1
7,200 or 12,000 | 7,200 | 120 | 60:1
12,000 or 20,125 | 12,000 | 120 | 100:1
17,200 | 18,000 | 120 | 150:1
20,125 or 34,500 | 20,125 | 115/67.08 | 175/300:1
60,000 | 34,500 | 115/69 | 300/500:1
69,000 | 40,250 | 115/67.08 | 350/600:1
115,000 | 69,000 | 115/69 | 600/1000:1
138,000 | 80,500 | 115/69 | 700:1
230,000 | 138,000 | 115/69 | 1,200/2000:1
500,000 | 287,500 | 115/69 | 2,500/4200:1