SP0551C01R04: Transformer Primary Injection Connection Schedule

TRANSFORMER PRIMARY INJECTION CONNECTION SCHEDULE

Primary Injection of YNd1 (or YNd11) Power Transformer with in-zone Earthing Transformer Confirmation of balance in differential and restricted earth fault protection systems

HV Injection LV Short configur configuratio Balance condition Reference CT configuration Measurements ation n (differential and REF) YNd1 YNd11 YNd1 YNd11 Test 1 A-N A-N a-b a-c Figure 1 Normal All CTs, relay displays Confirm balance Test 1a A-N A-N a-b a-c Figure 1 ‘A’ phase HV CT reversed Diff CTs, relay displays Measure spill current in diff and HV REF Test 2 B-N B-N b-c a-b Figure 1 Normal All CTs, relay displays Confirm balance Test 2a B-N B-N b-c a-b Figure 1 ‘B’ phase HV CT reversed Diff CTs, relay displays Measure diff spill current Test 3 C-N C-N c-a b-c Figure 1 Normal All CTs, relay displays Confirm balance Test 3a C-N C-N c-a b-c Figure 1 ‘C’ phase HV CT reversed Diff CTs, relay displays Measure diff spill current Test 4 A-C A-B a-n a-n Figure 2 Normal All CTs, relay displays Confirm balance Test 4a A-C A-B a-n a-n Figure 2 1) ‘a’ phase LV CT reversed Diff and ET CTs, relay Measure spill current in diff 2) ‘a’ phase LV ET CT displays and LV REF, operate shorted and disconnected current in ET o/c relay

Figure 1 0 C c 0 amps amps

0 amps B b 6.928 amps a 1 amp A 6.928 amps Illustration is for 132/11 kV Ynd1 ie N:1 where N = 6.928

V Secondary current = Primary current x N

Note there would be a 2-1-1 current distribution on the HV side if all three phases were supplied

Figure 2 1 amp C c 0 amps

0 ampsB b 0 amps V Illustration is for 132/11 kV Ynd1 1 amp A a 20.784 amps ie N:1 where N = 6.928

Secondary current = Primary current x 3 x N

Check this is the latest Process Zone version before use. Page 1 of 5 Form SP0511C01R04 Ver 1 Process Owner: John Cass, Assistant General Manager TaDS Ergon Energy Corporation Limited ABN 50 087 646 062 Ergon Energy Queensland Pty Ltd ABN 66 078 875 902 TRANSFORMER PRIMARY INJECTION CONNECTION SCHEDULE

Primary Injection of Yd1 (or Yd11) Power Transformer with in-zone Earthing Transformer Confirmation of balance in differential and restricted earth fault protection systems

HV Injection LV Short configur configuratio Balance condition Reference CT configuration Measurements ation n (differential and REF) Yd1 Yd11 Yd1 Yd11 Test 1 A-C A-B a-n a-n Figure 2A Normal All CTs, relay displays Confirm balance Test 1a A-C A-B a-n a-n Figure 2A ‘A’ phase HV CT reversed Diff CTs, relay displays Measure spill current in diff Test 1b A-C A-B a-n a-n Figure 2A 1) ‘a’ phase LV CT reversed Diff and ET CTs, relay Measure spill current in diff 2) ‘a’ phase LV ET CT displays and LV REF, operate shorted and disconnected current in ET o/c relay Test 2 B-A B-C b-n b-n Figure 2A Normal All CTs, relay displays Confirm balance Test 2a B-A B-C b-n b-n Figure 2A ‘B’ phase HV CT reversed Diff CTs, relay displays Measure diff spill current Test 3 C-B C-A c-n c-n Figure 2A Normal All CTs, relay displays Confirm balance Test 3a C-B C-A c-n c-n Figure 2A ‘C’ phase HV CT reversed Diff CTs, relay displays Measure diff spill current

Note – Neutral point of star winding is not accessible for connection (floating inside tank)

Figure 2A 1 amp C c 0 amps

0 ampsB b 0 amps V Illustration is for 132/11 kV Yd1 1 amp A a 20.784 amps ie N:1 where N = 6.928

Secondary current = Primary current x 3 x N

Primary Injection of YNyn0d1 (or Ynyn0d11) Power Transformer (with in-zone earthing transformer on Tertiary) Confirmation of balance in differential and restricted earth fault protection systems

HV Injection LV / TV Short configu configurati Balance condition Reference CT configuration Measurements ration on (differential and REF) d1 d11 d1 d11 Test 1 A-N A-N LV a-n LV a-n Figure 3 Normal All CTs, relay displays Confirm balance Test 1a A-N A-N LV a-n LV a-n Figure 3 ‘A’ phase HV CT reversed Diff CTs, relay displays Measure spill current in diff and HV REF Test 2 B-N B-N LV b-n LV b-n Figure 3 Normal All CTs, relay displays Confirm balance Test 2a B-N B-N LV b-n LV b-n Figure 3 ‘b’ phase LV CT reversed Diff CTs, relay displays Measure spill current in diff and LV REF Test 3 C-N C-N LV c-n LV c-n Figure 3 Normal All CTs, relay displays Confirm balance Test 3a C-N C-N LV c-n LV c-n Figure 3 ‘C’ phase HV CT reversed Diff CTs, relay displays Measure diff spill current Test 4 A-C A-B TV a-n TV a-n Figure 4 Normal All CTs, relay displays Confirm balance Test 4a A-C A-B TV a-n TV a-n Figure 4 1) ‘a’ phase TV CT reversed Diff and ET CTs, relay Measure spill current in diff and 2) ‘a’ phase ET CT shorted displays TV REF and operate and disconnected current in ET o/c relay Test 5 A-B B-C TV b-n TV b-n Figure 4 Normal All CTs, relay displays Confirm balance Test 5a A-B B-C TV b-n TV b-n Figure 4 ‘b’ phase TV CT reversed Diff CTs, relay displays Measure spill current Test 6 B-C A-C TV c-n TV c-n Figure 4 Normal All CTs, relay displays Confirm balance Test 6a B-C A-C TV c-n TV c-n Figure 4 ‘c’ phase TV CT reversed Diff CTs, relay displays Measure spill current Figure 3 0 C c 0 amps 0 B b 0 amps TV 1 amp A a 0 amps Illustration is for 66/33/6.6 kV YNyn0d1 HV Ie N:1 where N=2 (Primary/Secondary) c 0 amps V LV Secondary Current = Primary Current x N b 0 amps a 2 amps Earth connection can be left on Figure 4 1 amp C c 0 amps Illustration is for 66/33/6.6 kV YNyn0d1 TV 0 amps B b 0 amps Ie N:1 where N=5.773 (Primary/Tertiary) V 1 amp A a 17.32 amps Tertiary current = Primary current x 3 x N c 0 amps HV LV b 0 amps

a 0 amps

Check this is the latest Process Zone version before use. Page 3 of 5 Form SP0511C01R04 Ver 1 Process Owner: John Cass, Assistant General Manager TaDS Ergon Energy Corporation Limited ABN 50 087 646 062 Ergon Energy Queensland Pty Ltd ABN 66 078 875 902 Earth connection can be left on neutral bushing TRANSFORMER PRIMARY INJECTION CONNECTION SCHEDULE

Primary Injection of Dyn1 (or Dyn11) Power Transformer Confirmation of balance in differential and restricted earth fault protection systems

HV Injection LV Short configur Balance condition configu Reference CT configuration Measurements ation differential and REF) ration ( Dyn1 Dyn11 Test 1 A-C A-B a-n Figure 5 Normal All CTs, relay displays Confirm balance Test 1a A-C A-B a-n Figure 5 ‘a’ phase LV CT reversed Diff CTs, relay displays Measure spill current in diff and LV REF Test 2 A-B B-C b-n Figure 5 Normal All CTs, relay displays Confirm balance Test 2a A-B B-C b-n Figure 5 ‘b’ phase LV CT reversed Diff CTs, relay displays Measure diff spill current Test 3 B-C C-A c-n Figure 5 Normal All CTs, relay displays Confirm balance Test 3a B-C C-A c-n Figure 5 ‘c’ phase LV CT reversed Diff CTs, relay displays Measure diff spill current

Figure 5

1 amp C c 0 amps

B b 0 amps V 0 amps LV

1 amp A a 10.392 amps

Illustration is for 66/11 kV Dyn1 ie N:1 where N = 10.392

Secondary current = Primary current x N

Primary Injection of YNyn0d1 (or YNynd11) Power Transformer with delta tertiary grounded at one corner Confirmation of balance in differential and restricted earth fault protection systems

HV Injection LV / TV Short configu Balance condition configuration Reference CT configuration Measurements ration (differential and REF) d1 d11 d1 d11 Test 1 A-N A-N LV a-n LV a-n Figure 6 Normal All CTs, relay displays Confirm balance Test 1a A-N A-N LV a-n LV a-n Figure 6 ‘A’ phase HV CT reversed Diff CTs, relay displays Measure spill current in diff and HV REF Test 2 B-N B-N LV b-n LV b-n Figure 6 Normal All CTs, relay displays Confirm balance Test 2a B-N B-N LV b-n LV b-n Figure 6 ‘b’ phase LV CT reversed Diff CTs, relay displays Measure spill current in diff and LV REF Test 3 C-N C-N LV c-n LV c-n Figure 6 Normal All CTs, relay displays Confirm balance Test 3a C-N C-N LV c-n LV c-n Figure 6 ‘C’ phase HV CT reversed Diff CTs, relay displays Measure diff spill current Test 4* A-N A-N TV a-b/g* TV a-c/g* Figure 7 Normal All CTs, relay displays Confirm balance Test 4a* A-N A-N TV a-b/g* TV a-c/g* Figure 7 ‘a’ phase TV CT reversed Diff CTs, relay displays Measure diff spill current Test 5* B-N B-N TV b-c/g* TV a-b/g* Figure 7 Normal All CTs, relay displays Confirm balance Test 5a* B-N B-N TV b-c/g* TV a-b/g* Figure 7 ‘b’ phase TV CT reversed Diff CTs, relay displays Measure diff spill current Test 6* C-N C-N TV c-a/g* TV b-c/g* Figure 7 Normal All CTs, relay displays Confirm balance Test 6a* C-N C-N TV c-a/g* TV b-c/g* Figure 7 ‘c’ phase TV CT reversed Diff CTs, relay displays Measure diff spill current Figure 6 0 amps C c 0 amps

0 amps B b 0 amps Illustration is for 66/33/6.6 kV YNyn0d1 HV Ie N:1 where N=2 (Primary/Secondary) 1 amp A a 0 amps Secondary Current = Primary Current x N a 0 amps TV V b 0 amps

c 2 amps LV Figure 7 Illustration is for 66/33/6.6 kV YNyn0d1 0 amps c C 0 amps TV Ie N:1 where N=5.773 (Primary/Tertiary) HV 0 amps B b 5.773 amps Tertiary current = Primary current x N 1 amp A a 5.773 amps

c 0 amps * Note – when carrying out tests 4/4a, V 5/5a, 6/6a involving the delta phase that b 0 amps is permanently grounded, connect the short phase to ground (instead of a 0 amps LV phase to phase) for one of the tests to prove polarity of the grounding CT

Check this is the latest Process Zone version before use. Page 5 of 5 Form SP0511C01R04 Ver 1 Process Owner: John Cass, Assistant General Manager TaDS Ergon Energy Corporation Limited ABN 50 087 646 062 Ergon Energy Queensland Pty Ltd ABN 66 078 875 902