Your next chapter

Build deeper. Think system-wide.

A practical route from P&C commissioning to protection design, power-system studies and OT security. Three years. One connected roadmap.

Starting point · Module 01

Know what the relay sees.

Five weeks on CT ratios, residual current and the source-to-trip path, on the first stage of a fictional data campus you will keep growing for three years. Every session opens closed-book.

600/5 CT · 180 A primaryI secondary = 180 ÷ 120 = 1.50 A

Open your first module

A sustainable week

8 hours / week

Closed-book opener20 min per session: recall, one hand calc, one sketch1.0 h
Power / protection coreAttempt the derivation, then check the reference2.5 h
Campus buildAdd this module’s increment to the living system2.0 h
Automation / cyber threadNetworking, DNP3, IEC 61850, OT security1.0 h
Mixed set + spaced review6–10 problems from current + two earlier modules1.0 h
Error log + FeynmanRe-test due errors cold; explain one concept0.5 h

Busy week? Use four hours: 30 min closed-book opener, 90 min core, 60 min mixed set and due reviews, 60 min campus build. Skip new automation content, never the due reviews.

The learning standard

Recall before you read. Derive before you check. Verify it a second way, attack your own design, then defend it under review.

Scheme bench

Four decisions a relay actually makes

Not a catalogue. The quantity each function is looking at, and what “operate” means in the yard.

ANSI 21 · Distance

Interactive

Impedance is a stand-in for location.

The relay forms Z from voltage and current and asks whether that point sits inside a reach. Zone 1 covers the part of the line it may trip without waiting. Zone 2 looks past the remote bus, on a timer, so it can back up the next section without racing it.

01 / Develop the capability · October 2026 – September 2029

Twelve modules. One living system.

Every module is a five-week cycle built on retrieval, spacing and interleaving, and every artifact is added to one fictional data campus that grows from a single feeder to a 230 kV point of interconnection.

Weeks 1–3New material: derive, calculate, build the campus increment

Week 4Produce the module artifact and verify it independently

Week 5Consolidate: Attack the Design, Formal Review, Feynman checkpoint, error-log re-tests

Three gates on every major artifact

Independent Verification

Re-derive one key result by a different method or a ±20 % sensitivity on the dominant input.

Done · Results agree within a stated tolerance, or the difference is explained.

Attack the Design

List at least five realistic contingencies: what happens, is it acceptable, what would you change.

Done · Every contingency has a consequence and a decision.

Formal Review

After 48 hours, write at least eight senior-reviewer comments (Major / Minor / Clarification), then respond and revise.

Done · All Major comments closed; open items listed as limitations.

Year 1 · Modules 01–07

Foundations & measurement

P&C · W1–5

Know what the relay sees.

Stage 1 · one 13.8 kV feeder, one unit substation, one data hall.

Week 1Draw the stage-1 one-line from a written description. Mark zones, CT locations, polarity and overlap. Closed-book baseline test.
Week 2Derive CT and VT conversions; distinguish phase, residual (3I0) and a separate neutral CT. Ten conversions, each checked a second way.
Week 3Trace source → element → supervision → output → trip coil → breaker → interruption, as a diagram and as a numbered list.
Week 4Artifact: measurement and source-to-trip note plus phase and residual overcurrent test specification. Recompute every secondary value by hand.
Week 5Attack the Design: reversed polarity, open CT secondary, wrong ratio, VT fuse failure, residual vs neutral confusion. Formal Review. Feynman checkpoint.

Make it tangible · Labelled one-line rev A, conversion sheet, source-to-trip diagram and test specification.

Done when · Given a new CT ratio cold, predict metering within 1 % and explain what a pickup test leaves unproven.

Transformer protection · GE T60, SEL-487E/787, SIPROTEC 7UT

P&C · W6–10

Stable for everything outside the zone, on three platforms. Derive the physics once, then set it on each relay.

Stage 2 · T1 115/13.8 kV, 30/40 MVA, Dyn1, Z ≈ 10 %, 400 A NGR (fictional). Platform settings work replaces the campus build in weeks 2–4.

Week 1Physics first, closed-book: full-load currents and CT secondaries, Dyn1 phase shift, zero-sequence removal as a compensation matrix. Hand-check that a 3-phase 8 kA external 13.8 kV fault (960 A on the 115 kV side) cancels; separately, a 13.8 kV ground fault limited by the 400 A NGR, where the delta-side currents are not 960 A.
Week 2Ratio and vector compensation, two platforms in depth and the third as a mapping row. GE: sources, winding connection and angle; 1 pu = Unit CT (here the 2000 A LV CT). SEL-787: CTR1/2, TAP1/2, W1CTC/W2CTC, auto TAP only if TAPmax/TAPmin ≤ 7.5. SEL-487E: per-terminal CT, tap and compensation settings with ICOM, TAPMAX/TAPMIN ≤ 35. Siemens: object data and vector group, I/IrObj. The same through-fault is 4.78 × TAP, 4.78 I/IrObj and 4.0 pu on GE; explain why.
Week 3Operate/restraint: GE minimum pickup, Slope 1, Break 1, Break 2, Slope 2. SEL-787 O87P, SLP1, IRS1, SLP2, U87P. SEL-487E adaptive slope: SLP2 applies only when an external fault is detected, with no IRS1. Siemens thresholds and slopes in SIPROTEC 4 and SIPROTEC 5 naming. Plot the same campus faults on each. Harmonic blocking (SEL-787 HBLK) vs restraint (HRSTR), crossblocking, REF vs 87T coverage.
Week 4Artifact: side-by-side settings basis for T1 on two or three platforms, including the manual revision used. Slope test points for an injection set in each relay’s per-unit base, converted to secondary amps per winding; on the 487E, simulate an external fault to test SLP2. Hand-check two points per platform; ±10 % tap sensitivity.
Week 5Attack the Design, with vendor-specific failures: wrong compensation matrix, wrong vector group or winding angle, a 487E test that ignores adaptive slope, CT saturation, extreme tap, inrush from a weak source, CT-ratio change with 87 settings unchanged. Formal Review. Feynman checkpoint.

GE T60 · compensation from source, winding connection and grounding inputs · 1 pu = Unit CT primary · dual slope with breakpoints, restraint = max · 2nd-harmonic inrush and 5th-harmonic overexcitation inhibit, restricted ground fault (mode and element names: verify in manual).
SEL-787 · CTR1/2, TAP1/2, W1CTC/W2CTC · O87P, SLP1, IRS1, SLP2, U87P · PCT2/PCT4/PCT5 with HBLK or HRSTR.
SEL-487E · per-terminal CT, tap and compensation settings with ICOM (verify names against your revision) · O87P, SLP1, SLP2 adaptive, U87P, no IRS1 · harmonic and REF setting names: verify in manual.
SIPROTEC 7UT · SIPROTEC 5: I-DIFF: Threshold, Slope 1/2 with Intersection 1/2 Irest, I-DIFF fast: Threshold, Crossblock. time 2nd har., Blocking with 3rd/5th harm. · SIPROTEC 4 equivalents I-DIFF>, base points, I-DIFF>> (verify in manual).

Make it tangible · Portfolio P1 · application note, per-platform source map and test matrix, side-by-side settings basis table (logic, naming, per-unit base, compensation, harmonic method, REF, test approach, differences, manual revision), vendor-specific Attack the Design, review record.

Done when · Given a new transformer cold, set compensation and compute a slope-1 test point on any of the three platforms, and explain on each how a CT-ratio change can alter differential behaviour with the 87 fields unchanged.

Fault analysis & sequence networks

Power systems · W11–15

Fault physics to relay quantities.

Stage 3 · second 115 kV source and T2; 13.8 kV main-tie-main; max/min source impedance.

Week 1Derive per-unit bases and base change; Thevenin equivalents of each source at max and min.
Week 2Symmetrical components by hand, phase → sequence → phase, sketched as phasors.
Week 3Sequence networks for 3φ, SLG, LL and LLG; vary grounding and tie open/closed.
Week 4Artifact: fault-study memo with a case table. Verify against a small software or scripted model; explain any difference above 5 %.
Week 5Attack the Design: missing zero-sequence source, wrong transformer connection, unknown X/R, motor contribution, generator in service. Formal Review. Feynman checkpoint.

Make it tangible · Fault-study memo and the assumptions register reused through Year 2.

Done when · Distinguish total bus fault current from the current through a particular relay, for three cases cold.

Digital substations & automation · IEC 61850

Automation / OT · W17–21

Trace every signal from source to screen to trip coil.

Stage 4 · station bus on the stage-3 assets: T1/T2 bays, Main 1, tie, Main 2, unit-substation feeder.

Week 1Draw the station network from a written description. VLANs, multicast, PRP/HSR. Data model with functional constraints; map T1 functions to PDIF, PTOC, PTRC, XCBR, XSWI, CSWI and CILO.
Week 2Points list for the stage-3 assets (LN path with FC or DNP3 index, scaling, quality, report control block, destination) and the EPMS signal map.
Week 3GOOSE/dataset map for differential trip, lockout and the main-tie-main interlock: GoCB fields, LGOS supervision, test vs simulation vs q.test. SCL roles by tool. Time sync: SNTP, IRIG-B, PTP and time-quality bits.
Week 4Artifact: points list, EPMS map, GOOSE/dataset map and cyber boundary v1 with zones, conduits and target security levels. Trace three signals end to end.
Week 5Attack the Design: lost GOOSE, wrong confRev, test bit left set, loss of time sync, flat network, utility link compromise. Formal Review. Feynman checkpoint.

Make it tangible · Portfolio P2 · automation and cyber boundary package v1, extended in Modules 05, 07, 09 and 11.

Done when · Trace a new signal cold and distinguish connectivity, mapping, timestamp and application-logic failures.

Overcurrent & coordination · SEL-751, GE F60/850, SIPROTEC 7SJ

P&C · W23–27

Coordination in every operating mode, set on three feeder platforms.

Stage 5 · four 13.8 kV feeders, 2N A/B distribution, UPS and standby generators at 480 V, one 13.8 kV ungrounded double-wye capacitor bank on Main 2 (fictional). Platform settings work replaces part of the campus build in weeks 2–4.

Week 1Physics first, closed-book: pickup constraints from maximum load (including N+1 transfer load) vs minimum fault, using Module 03 values; residual (3I0) vs neutral CT pickup; cold-load inrush.
Week 2Inverse-time curves from the equation and stated constants, clearing time and a derived coordination margin. Then enter the same feeder curve on each platform: SEL-751 51P1P/51P1C/51P1TD with U1–U5 and C1–C5, GE F60 (IEEE, IEC, IAC, I²t, FlexCurves) and Multilin 850 (adds ANSI and I⁴t; pickup in × CT, TDM), SIPROTEC 7SJ Ip, curve and time dial (IEC vs ANSI multiplier scaling). Show why the same curve needs different TD numbers on IEC and US families, and on IEEE vs ANSI within GE, and compare electromechanical vs instantaneous reset.
Week 3Directional elements and polarization on each platform (forward definition, polarising quantity, characteristic angle); coordinate three devices on strong source, weak source and generator. Capacitor bank (lighter): ungrounded double-wye protected by 60N neutral-current unbalance from a CT between the two neutrals (59NU on a single ungrounded wye shown for contrast only), inherent-unbalance compensation, alarm and trip stages from element-failure counts.
Week 4Artifact: coordination study with TCCs per operating mode, settings rationale and a side-by-side feeder settings table on two or three platforms (curve, pickup, TD, reset, directional polarising, cold-load logic, test points in secondary amps). Hand-check two operating times per platform. Extend the P2 maps to four feeders and 2N A/B.
Week 5Attack the Design: generator-only source, closed-transition paralleling, one 2N side out, cold-load pickup, wrong setting group, IEC TD entered on a US curve or IEEE TD on an ANSI curve, capacitor unbalance setting with no inherent-unbalance compensation. Formal Review. Feynman checkpoint.

SEL-751/751A · 50P/51P, 50G/51G, 50N/51N · 51P1P, 51P1C (U1–U5, C1–C5), 51P1TD, 51P1RS electromechanical reset Y/N (verify in manual) · directional 67 with ORDER/polarising settings (verify in manual) · cold-load via setting groups or logic.
GE UR F60 · Phase TOC: curve IEEE, IEC A/B/C/short, IAC, I²t, FlexCurves; no ANSI family · directional characteristic angle and polarising (verify in manual).
GE Multilin 850 · Phase TOC: PICKUP in × CT (0.050–30.000), CURVE adds ANSI Extremely/Very/Normally/Moderately Inverse and I⁴t, FlexCurve A–D, definite time, TDM 0.05–600.00, RESET Instantaneous/Timed · directional settings (verify in manual).
SIPROTEC 7SJ (7SJ80/82 SIPROTEC 4–5) · 50/51: I>, I>>, Ip with T Ip / D Ip, IEC or ANSI curve · 67/67N direction with polarising and angle · all names and SIPROTEC 4 vs 5 naming (verify in manual).
Capacitor bank (lighter) · double-wye, ungrounded: 60N neutral-current unbalance is the primary method; 59NU (single ungrounded wye with neutral VT) for contrast only · inherent-unbalance compensation on SEL-487V (60N nulling), GE C70 and SIPROTEC 7SJ85 (names and ranges: verify in manual). One-row mapping in the P3 table.

Make it tangible · Portfolio P3 · integrated fault and coordination study (Modules 03 + 05, one model, one assumptions register) with side-by-side feeder settings table (logic, naming, curve scaling, reset, directional supervision, test approach, manual revision) and a capacitor-unbalance mapping row.

Done when · Diagnose a seeded miscoordination cold: pickup, timing, curve shape, curve-family scaling or system change, and re-enter the fix on any of the three platforms.

Distance protection · SEL-421/311L, GE D60, SIPROTEC 7SA

P&C · W29–33

Impedance to reach to test phasors, entered on three platforms.

Stage 6a · 230 kV POI with a short utility line. Platform settings work replaces part of the campus build in weeks 2–4.

Week 1Physics first, closed-book: primary to secondary ohms (CTR/PTR); R-X zones for the POI line; short-line and SIR challenges; Zone 1 underreach, Zone 2 and Zone 3 or reverse zone purpose.
Week 2Phase and ground loops; derive k0 = (Z0 − Z1)/(3Z1) from line data, then convert it into each vendor’s convention: SEL-421 k0M1/k0A1 (Zone 1) and k0M/k0A, GE D60 Z0/Z1 magnitude and angle, SIPROTEC 7SA RE/RL and XE/XL or K0 and angle. Define each form: k0 = (Z0 − Z1)/(3Z1) is complex (SEL, Siemens K0); RE/RL = (R0 − R1)/(3R1) and XE/XL = (X0 − X1)/(3X1) are separate scalar ratios, not |k0|; GE enters the ratio Z0/Z1 = 1 + 3k0, not k0. All are dimensionless, so CTR/PTR does not change them. Worked check: Z1 = 2 + j20 Ω, Z0 = 7 + j60 Ω gives k0 = 0.669∠−1.41°, RE/RL = 0.833, XE/XL = 0.667, Z0/Z1 = 3.005∠−0.94°, and the SLG loop Z1(1 + k0) = 33.53 Ω∠83.72° on every form. Enter the same line on two platforms in depth, the third as a mapping row.
Week 3Mho vs quadrilateral on each platform (resistive reach, tilt or directional supervision), fault resistance, load encroachment, BESS infeed (what-if, stage 7 preview), loss-of-potential supervision; why short lines favour pilot or line differential.
Week 4Artifact: reach calculations, R-X plot, side-by-side distance settings table on two or three platforms and at least six boundary tests per platform in that relay’s own units. Verify two apparent impedances by hand from sequence quantities; ±10 % k0 sensitivity.
Week 5Attack the Design: high SIR, wrong k0 convention (|k0| 0.669 entered as RE/RL 0.833, or GE Z0/Z1 3.005 entered as SEL k0), CVT transients, generation infeed (what-if), loss of VT with LOP blocking disabled, test set using a different k0 form than the relay. Formal Review. Feynman checkpoint.

SEL-421 / SEL-311L · Z1MAG/Z1ANG, Z0MAG/Z0ANG line data · mho Z1P–Z5P, quadrilateral XG/RG · k0M1/k0A1 Zone 1, k0M/k0A other zones; SEL-311L: same names, k0M/k0A appear only with EADVS = Y · XG/RG quadrilateral reach · LOP and load encroachment (ZLF/ZLR: verify in manual).
GE D60 (and L90 backup distance) · positive and zero-sequence line impedance · Z0/Z1 magnitude and angle per zone (= 1 + 3k0; names verify in manual) · mho or quad shape, directional angle and comparator limit · VT fuse failure and load encroachment (names: verify in manual).
SIPROTEC 7SA (7SA6 / 7SA8x) · RE/RL and XE/XL or K0 and angle(K0) by parameter choice (strings: verify in manual) · polygon (quad) and mho zones Z1–Z5 · fuse-failure monitor and load encroachment · SIPROTEC 4 vs 5 naming (verify in manual).
Test approach · confirm which k0 form the injection set uses and convert before testing; check reach on phase and ground loops at line angle and at load angle on each platform.

Make it tangible · Reach calculation set, R-X plot, side-by-side distance settings table (logic, naming, residual compensation form, supervision, test approach, manual revision) and boundary test list, feeding P4.

Done when · Convert, plot and justify reach for a new line cold, express the same k0 in all three vendor forms, and say why distance alone may be inadequate here.

Pilot, line differential, bus & breaker failure · SEL-411L/487B/451, GE L90/B30/C60, SIPROTEC 7SD/7SS

P&C · W34–38

Across terminals, across the bus and through the breaker, on three platforms.

Stage 6b · both POI line terminals; 230 kV POI bus; two 230/34.5 kV transformers. Platform settings work replaces part of the campus build in weeks 2–4.

Week 1POTT, PUTT, DCB, DCUB and line differential compared for the POI line (DTT is transfer trip for breaker failure and remote trip, not a pilot comparison); choose and justify. Line differential on each platform: SEL-311L/411L alpha plane (87LR radius, 87LANG blocking angle), GE L90 adaptive per-phase restraint, SIPROTEC 7SD threshold with charging-current compensation. Pickups (87LPP, 87L2P, 87LGP) must sit above line charging current. Channel asymmetry: a ping-pong delay estimate assumes equal go and return paths; Δ = 1 ms is about 21.6° at 60 Hz.
Week 2Truth tables: permissive receipt, channel loss, weak infeed/echo, current reversal, and a DCUB row for loss of guard plus permissive (unblock window typically about 150 ms: verify in manual). Map the chosen scheme onto each platform’s logic (SELOGIC control equations, GE FlexLogic, Siemens CFC) and name where each vendor’s built-in scheme replaces custom logic.
Week 3Breaker failure and bus differential, two platforms in depth and the third as a mapping row. BF: current detector pickup below minimum fault; delay ≥ breaker interrupt time (about 2–3 cycles at 230 kV) + current-detector dropout + margin, roughly 6–9 cycles; retrip and backup timers; no-current logic (SEL ENCBF1) for low-current faults. Bus: low-impedance 87B on the 230 kV POI bus (mixed CT ratios, zone selection from disconnector status; high impedance needs matched CTs and has no zone selection): check zone, slopes, CT saturation handling. Add BF GOOSE to the Module 04 dataset map.
Week 4Artifact: logic diagrams, trip matrix and side-by-side tables (two platforms in depth, third as a mapping row) for line differential, BF and 87B on two or three platforms (logic, naming, supervision, timers, slopes and saturation method, test approach, manual revision). Verify the clearing-time budget against Module 03 fault levels; hand-check one bus slope point and one BF timing chain per platform: relay + BF delay + backup breaker + DTT channel against the Module 03 clearing-time budget. Reclosing and sync-check philosophy (moved from week 3).
Week 5Attack the Design: channel failure during fault, failed campus breaker, BF current detector above minimum fault, retrip disabled, CT saturation on an external bus fault, disconnector status wrong in zone selection, weak BESS infeed (what-if), wrong DTT routing, time-reference error. Formal Review. Feynman checkpoint.

Line differential · SEL-311L: 87LPP, 87L2P, 87LGP, 87LR, 87LANG, pickups above charging current · SEL-411L: same names (verify in manual) · GE L90 per-phase adaptive restraint, GPS channel option (verify in manual) · SIPROTEC 7SD I-DIFF threshold, charging-current compensation (verify in manual).
Breaker failure · SEL 400 series, per breaker (suffix 1, 2 for BK2): 50FP1, BFPU1, RTPU1, BFI3P1/BFIDO1/BFISP1, ENCBF1 no-current logic, EBFL1 enable (SEL-421 manual; SEL-451 from a secondary source; SEL-487E: verify in manual) · GE C60/D60: current supervision, timers 1–3, retrip (verify in manual) · SIPROTEC 7SS52: I> BF; 7SJ/7SA: 50BF threshold, T1 local retrip, T2 backup trip (parameter strings: verify in manual).
Bus differential · SEL-487B: CTnnBZx terminal-to-zone assignment, TAPnn = CTRMAX·INOM/CTRnn (up to 10:1 ratio mismatch), O87P (verify range), SLP1/SLP2 with external-fault detection (CON1) switching to SLP2, directional supervision, sensitive 87ST/E87SSUP · GE B30: biased dual slope, saturation detector, directional supervision (verify in manual) · SIPROTEC 7SS52: STAB FAC:BZ/CZ (k), Id> BZ/CZ, k = 0.6 when CT burden factor Kb < 2, otherwise calculate · 7SS85: characteristic slope and threshold (verify in manual).
Test approach · line differential with a GPS-synchronised or loop-back test; BF by timing from initiate to retrip and backup trip with current removed and held; 87B slope points with a simulated external fault on each platform.

Make it tangible · Logic diagrams, trip matrix and side-by-side line differential, breaker-failure and bus-differential tables, feeding P4.

Done when · Produce a correct trip matrix cold for healthy and failed channels and a failed breaker, set a BF timing chain and one 87B slope point on any of the three platforms, and explain how each vendor keeps 87B stable for CT saturation.

Year-1 integration · W39–44

Portfolio P4: one protection and automation philosophy for the path 230 kV POI → 230/34.5 kV transformers → 34.5 kV ring → 34.5/13.8 kV unit transformers → 13.8 kV halls, including retirement of the 115 kV legacy supply, the updated P2 maps and a draft standards compliance matrix. Closes with a 15-minute recorded defence of five decisions.

Years 2–3 · Modules 08–12

Power-system studies · PSS/E

Power systems · Year 2

Load flow and contingency, then short circuit → coordination → IEEE 1584 arc flash on one model.

Stage 7 · BESS and generation intertie, all operating modes.

Make it tangible · Portfolio P5 · integrated studies package with arc-flash sensitivity and a mitigation comparison.

Protection design & documentation

Design · Year 2

Bay design, AC/DC schematics, CT allocation vs Sampled Values, DC duty and transfer schemes.

Stage 7 · BESS bays join the station bus; Sampled Values on one bay.

Make it tangible · Portfolio P6 · bay design package, FAT/SAT outline and compliance matrix.

Event analysis & troubleshooting

P&C · Year 2

COMTRADE, GOOSE/SV/SOE timelines, competing hypotheses, inverter-source fault behaviour.

Stage 7 · synthetic events on the full Year-2 campus.

Make it tangible · Portfolio P7 · two synthetic event investigations separating evidence, inference and unknowns.

Practical OT cybersecurity

OT security · Year 3

Zones and conduits across the full campus, engineering access, baseline and restore, logging.

Stage 8 · the Module 04 boundary extended to BESS, generation and the 230 kV yard.

Make it tangible · Portfolio P8 · extended boundary drawing, risk register and a demonstrated restore record.

Integration & technical leadership

Integration · Year 3

Full-campus protection and automation philosophy and its trade-offs.

Stage 9 · the full campus.

Make it tangible · Portfolio P9 · capstone package, review record and a 15-minute defence of five decisions.

Spaced review · Year 1

Module	Taught	Review 1	Review 2
01 Foundations & measurement	W1–5	W8	W12
02 Transformer protection	W6–10	W14	W17
03 Fault analysis	W11–15	W18	W21
04 Digital substations & automation	W17–21	W24	W27
05 Overcurrent & coordination	W23–27	W30	W33
06 Distance protection	W29–33	W35	W40
07 Pilot schemes & breaker failure	W34–38	W41	W46

W1–48 scheduled: 35 module weeks + 3 gap weeks (W16, W22, W28) = W1–38, integration package W39–44, buffer W45–48. W49–52 are leave and holidays, not scheduled.
Quarterly cumulative exams: W13, W26, W45 and W48. Buffer weeks hold the W45 exam, the W46 review and the W48 exam.
At most one scheduled review or exam in any week. Reviews use the 1-hour mixed-set block; no extra hours.

The living system · Northfield Data Campus (fictional)

Stage 1 · 01One 13.8 kV utility feeder, one 13.8 kV/480 V unit substation, CTs/VTs, one data hall.
Stage 2 · 02T1: 115/13.8 kV, 30/40 MVA, Dyn1, Z ≈ 10 %, 400 A NGR, CTs 300:5 and 2000:5.
Stage 3 · 03Second 115 kV source feeding T2 (identical to T1). Main-tie-main: Main 1 from T1, Main 2 from T2, normally-open tie.
Stage 4 · 04IEC 61850 station bus on the stage-3 assets, GOOSE trips and interlocks, EPMS meters, DNP3 gateway, cyber boundary v1.
Stage 5 · 05Four 13.8 kV feeders, 2N A/B distribution, UPS and standby generators at 480 V, one 13.8 kV capacitor bank on Main 2.
Stage 6 · 06–07230 kV POI line and bus, two 230/34.5 kV transformers, 34.5 kV ring, 34.5/13.8 kV unit transformers T3/T4. The 115 kV supply, T1 and T2 retire in the integration package.
Stage 7 · 08–1034.5 kV BESS and generation intertie, N+1 capacity, transfer schemes, Sampled Values on one bay.
Stage 8 · 11Full OT security across every zone: engineering access, baseline and restore, logging.
Stage 9 · 12Full campus, defended end to end.

Portfolio · nine pieces

More reliable judgement. Stronger technical evidence.

P1Transformer applicationModule 02
P2Automation & cyber boundary package v1Module 04
P3Integrated fault & coordination study, multi-platform feeder tableModules 03 + 05
P4Year-1 campus protection & automation packageW39–44
P5Integrated studies package (short circuit, coordination, arc flash)Module 08
P6Bay design packageModule 09
P7Event investigationModule 10
P8OT security package (extends P2)Module 11
P9Capstone defenceModule 12

Each piece carries an assumptions register, verification, Attack the Design table, review record, standards compliance matrix (applicable editions) and stated limitations. Fictional systems and permitted public data only; every piece is labelled as training work.

Start PSS/E early.Check access in week one and use it for the Module 03 verification; don’t wait until Module 08.

Keep credentials focused.Continue the P.Eng. work separately. Choose one additional exam when it supports a specific role and fits the workload.

Protection / power studies / OT security · Updated 2 Nov 2026

From commissioning to integrated consulting.

Build the engineering judgement and cybersecurity capability to deliver reviewed power-system services. A three-year sequence, starting with twelve practical weeks of five-week module cycles.

3 yearsOctober 2026 – September 2029

8 hoursWeekly study budget

9 piecesCore portfolio evidence

Updated 2 November 2026 · W1–48 scheduled ≈ 384 h/year · 1,152 h over three years · 4 weeks leave

Purpose

A companion to the protection plan, not a second workload.

Build toward a practice that combines protection engineering, power-system studies, commissioning, event investigation, and operational technology cybersecurity. About eight years of P&C commissioning and the B.Tech are the starting point. The main development needs are independently deriving and defending designs, validating models, producing reviewable reports, and securing the systems that implement protection.

This is a service-development companion to the existing protection development plan, reviewed in its 2 October 2026 version. That document remains the detailed protection-topic reference. Use this schedule to prioritize it. Do not run both schedules as additional workloads. The calendar is a planning estimate, not a prediction of professional competence or business income.

Recommended initial positioning: protection, commissioning, and event-analysis expertise with secure substation communications capability.

Broader consulting can follow through supervised project delivery and collaboration with specialists. A small firm need not deliver every specialty through one person. The twelve-module learning roadmap is the protection-topic reference. Open the modules.

1 · Evidence

Translate the target services into evidence.

NERX’s site lists eight service areas. The cyber links and learning projects below are proposed additions for this development plan, not claims about NERX’s cybersecurity offering.

Target service	Knowledge to develop	Portfolio evidence	Cybersecurity connection	Sequence
Protective relaying and testing	Settings rationale, coordination, CT/VT application, logic, test design	Reviewed feeder and transformer settings calculations with commissioning matrices	Approved settings baselines, access control, change tracking and recovery	First
Protection misoperation investigation	COMTRADE, phasors, digital chronology, relay logic and breaker behaviour	Three event reports distinguishing evidence, inference and unresolved questions	Correlate event, access and configuration records; distinguish cyber hypotheses from ordinary faults	First
One-lines and equipment sizing	Operating arrangements, load duty, fault duty, grounding, instrument transformers	One-line, equipment schedule, design assumptions and checks	Asset inventory and communication architecture derived from the physical design	First–second year
Power-system analysis	Load flow, short circuit, coordination, motor starting and stability	Validated model, scenarios, sensitivity study and engineering report	Protect model integrity and change history	Second year onward
Arc-flash analysis and mitigation	Fault and arcing-current models, clearing times, equipment geometry and operating modes	Supervised study with documented inputs, sensitivity and mitigation comparison	Control protection-setting changes that could alter clearing time	Second year onward
Power-quality investigation	Sags, interruptions, harmonics, unbalance, resonance and measurement quality	Measurement plan and synthetic/public-data diagnostic report	Separate process disturbances from communication and data-quality failures	Second year onward
Generator interconnection coordination	Utility requirements, model submissions, generator/IBR behaviour and studies	Fictional interconnection requirements and model-validation package	Secure plant-controller and utility communication interfaces	Third year onward
NERC compliance programs	Applicability, responsibilities, evidence, maintenance and corrective actions	Mock applicability register and evidence package	CIP assessment and evidence where applicable	Build gradually

2 · Operating rules

Eight hours, and what a busy week becomes.

Use eight hours a week over 48 active weeks a year. Reserve four weeks annually for outages, exams and recovery. Field learning supports this plan. It is not automatically equivalent to study or independent design experience.

During heavy work or MEng periods, use four hours: 30 minutes closed-book recall, 90 minutes core, 60 minutes mixed set and due reviews, 60 minutes campus build. Never skip due reviews. Count overlapping academic assignments toward the plan. Do not add eight hours on top of a full course workload.

Every project follows predict → calculate → simulate or test → reconcile differences → document → obtain review. Use fictional systems and public or expressly permitted data. Keep workplace settings, drawings, credentials and event files inside authorized systems. Personal simulations do not authorize live-system tests or changes.

Weekly block	Hours	Output
Closed-book opener	1.0	Recall, one hand calculation and one sketch before notes open
Power and protection core	2.5	One worked derivation, checked against the reference
Campus build	2.0	This module’s increment to the fictional campus
Automation and cyber thread	1.0	One configured, observed or documented control
Mixed set and spaced review	1.0	Interleaved problems and due review cards
Error log and Feynman	0.5	Cold re-tests and a three-minute explanation

3 · First 90 days

One fictional station. Twelve connected exercises.

Use the fictional Northfield Data Campus: one 13.8 kV feeder in week 1, then T1 (115/13.8 kV, 30/40 MVA, Dyn1, resistance-grounded through a 400 A NGR), then a second 115 kV source with T2 and a 13.8 kV main-tie-main. Each stage is validated before the next is added; BESS and generation come in Year 2.

Choose and document source sequence impedances, transformer impedance and base, CT/VT ratios, loads, line impedances and breaker clearing assumptions. Invented inputs must be labelled training assumptions. No outputs are field settings.

Week	Power and protection	Cyber and network	Deliverable
1	Draw the stage-1 one-line from a written description; mark zones, CTs, polarity and overlap; closed-book baseline	Draw devices and data flows; identify switch, router and firewall roles	One-line rev A and baseline assessment
2	CT and VT conversions; phase, residual and separate neutral CT	IPv4 addressing, subnets and routing; plan three lab segments	Conversion sheet and IP-address plan
3	Source-to-trip path as a diagram and a numbered list	Inspect ARP, ICMP and TCP on the isolated lab	Source-to-trip diagram and annotated capture
4	Module 01 artifact: measurement note and overcurrent test specification, verified by hand	Separate engineering, station and monitoring roles in the lab design	Test spec and segmentation rationale
5	Module 01 consolidation: Attack the Design, Formal Review, Feynman checkpoint	Accounts, least privilege and administrative access	Review record and access matrix
6	T1 full-load currents, vector group, grounding and zero-sequence removal	Configure a simple allowlist; prove one permitted and one denied flow	Calculation sheet and firewall verification record
7	Ratio matching and vector compensation, derived then set on GE, SEL and Siemens	Baseline a fictional configuration; compare and explain revisions	Compensation derivation per platform and change record
8	Operate/restraint, slopes and harmonics on each platform; REF vs 87T coverage; Module 01 Review 1	Back up and restore a lab configuration; verify behaviour afterward	Characteristic points and restore evidence
9	Module 02 artifact: side-by-side settings basis on two or three platforms, test matrix incl. REF/87G	DNP3 points, classes and quality on the lab gateway	Portfolio P1 draft
10	Module 02 consolidation: Attack the Design, Formal Review, Feynman checkpoint	Compare device time sources and timestamp quality	P1 with review record; time-quality note
11	Per-unit bases and Thevenin sources at max and min (stage 3: T2 and main-tie-main)	Station network sketch for the stage-3 assets	Source model and network sketch
12	Symmetrical components by hand; Module 01 Review 2	VLANs and multicast basics ahead of Module 04	Worked sequence-component set

Use any remaining days for correction and review. If calculations or input scaling remain unreliable, repeat the relevant exercises before adding more automation.

4 · Weeks 11–44

Deepen protection and operational security.

Period	Main learning	Required project	Completion evidence
W11–15 · Module 03	Fault analysis and sequence networks across source and tie arrangements	Fault-study memo and the shared assumptions register	Distinguish bus fault current from relay current for three cases cold
W17–21 · Module 04	IEC 61850 data model, points list, EPMS map, GOOSE/datasets, SCL roles, time sync; DNP3 to the utility; zones and conduits	Portfolio P2: automation and cyber boundary package v1	Trace a signal end to end; distinguish connectivity, mapping, timestamp and logic failures; conceptual mapping flagged as untested
W23–27 · Module 05	Overcurrent and coordination on utility, weak source and generator; 2N A/B	Portfolio P3: integrated fault and coordination study; P2 extended to four feeders	Diagnose a seeded miscoordination cold
W29–38 · Modules 06–07	Distance, POTT/DCB/DTT, line differential, breaker failure, reclosing and sync check at a 230 kV POI	Reach set, R-X plot, logic diagrams and trip matrix; BF GOOSE added to P2	Correct trip matrix for failed channel and failed breaker, cold
W39–44 · Integration	Protection and automation philosophy for the whole Year-1 campus; 115 kV supply retired	Portfolio P4: Year-1 campus protection and automation package	All three gates closed; 15-minute defence of five decisions

First-year success means stronger commissioning judgement and readiness for supervised settings, design, studies and OT assignments. It does not mean mastery of every relay family or independent readiness for the entire service catalogue.

Do not install a generic IT security appliance in a time-critical protection path simply because it is a security control. Learn the actual protocol, forwarding path, redundancy and latency requirements, then validate any proposed control’s effect. Ordinary station GOOSE is a Layer-2 topic. Treating every protection message as routed TCP traffic creates design errors.

5 · Second year

Studies, design and assessed OT security.

Quarter	Power work	Cybersecurity work	Client-style output
Q5	Load-flow convergence, bus voltage, transformer taps, reactive power and normal/contingency operation	OT inventory, zones and conduits, and risk assessment	Study report with assumptions, operating cases and a prioritized OT risk register
Q6	Maximum and minimum fault levels, breaker duty and coordination across source arrangements	Secure engineering access, account lifecycle, backup and recovery	Reviewed short-circuit and coordination package, plus an access-and-recovery design
Q7	Arc-flash methodology and mitigation under experienced review; motor starting and power-quality foundations	Logging, passive traffic baselines and an incident-response tabletop	Mitigation comparison and incident playbook; separate validated results from training-only exercises
Q8	One-lines, sizing basis, station DC and tripping requirements, and design interfaces	Configuration management and procurement security requirements	Integrated design basis, equipment schedule and acceptance-test specification

Aim for participation in at least two actual reviewed assignments in a chosen specialty, where access and role permit. Two projects are an exposure target, not a universal threshold of competence. Seek responsibility for complete deliverables and their revisions, rather than only executing someone else’s checklist.

6 · Third year

Choose depth. Establish repeatable delivery.

Choose one primary commercial direction while maintaining the shared foundation.

Utility protection and digital substations — recommended first fit. Complex settings, scheme assurance, event analysis, station networks and OT security. It builds most directly on field experience.
Industrial reliability consultancy. Short circuit, coordination, arc flash, motor starting, power quality and industrial control-system security. This requires more industrial equipment and operating-context exposure.
Generation and BESS interconnection. Load flow, dynamic models, inverter-based resources, protection interactions and secure plant communications. Add RMS versus EMT distinctions, model limitations and project-specific interconnection requirements before offering independent study conclusions.

Across quarters 9–12, complete a specialist capstone, contribute to progressively more demanding reviewed projects, write a delivery procedure and build a reusable QA checklist. Learn scoping, assumptions, exclusions, change orders, estimates, schedule risk, peer review, records retention and professional liability arrangements alongside the technical work.

Three years can build substantial additional capability with consistent practice and relevant assignments. Broad independent consultancy may take longer, particularly for dynamics, interconnection and arc-flash work. Expand by demonstrated competence, not a launch-date promise.

7 · Credentials

Recommended investments, not a mandatory list.

Priority	Credential or training	Suggested timing	Decision rule
Ongoing	P.Eng. pathway and applicable practice authorization	Continue alongside all phases	Central to the engineering-service objective. Eligibility and approval remain regulator decisions.
1	Networking fundamentals at CCNA depth	Start now; exam optional in year 1–2	Pass practical subnet, routing, segmentation and troubleshooting gates before advanced OT security.
2	CompTIA Security+	First cyber exam if a broad foundation is needed; roughly months 4–9	Use the current official objectives for the exam actually booked. This plan does not assume a SY0-801 launch date.
3	Applied relay and vendor training	One targeted course in year 1	Choose the course that addresses a measured settings or test gap on equipment you use.
4	ISA/IEC 62443 fundamentals, then a relevant assessment or design certificate	Year 2	Prioritize when preparing risk assessments or security architectures. Complete the required prerequisites.
5	GICSP	Year 2–3, preferably funded by an employer	Worth considering after practical networking and OT work. It connects IT, engineering and control-system security.
Later	Specialist detection/response or a project-management credential	Only when the intended service needs it	Avoid diverting first-year time from core engineering and networking competence.

Cisco’s CCNA scope includes networking, connectivity, services, security and automation. ISA offers a staged industrial-security certificate program; it is distinct from professional engineering licensure. GICSP covers industrial systems security across the lifecycle.

Do not purchase several exam vouchers or expensive study platforms at once. Begin with existing textbooks, manuals, official objectives and lab work. Take one funded specialist course after a concrete gap emerges.

8 · Reference shelf

How to use the standards, not a compliance specification.

Use Power System Relaying, fifth edition, and Protective Relaying: Principles and Applications, third edition. Pair every concept with the exact manual for the relay model, firmware, options and configured source. SEL ePROT 401 is a relevant engineer-oriented foundations option; ePROT 405 provides industrial applications and settings exercises. Neither substitutes for hands-on relay work.

This table is a reading map. NERC’s portal provides standards and implementation materials. PRC-004, PRC-005 and PRC-027 are particularly relevant to misoperations, maintenance and coordination. NERC applicability is not established simply because a client owns a substation.

Start the cyber reading with NIST SP 800-82 Rev. 3: OT architecture and characteristics, threats and vulnerabilities, risk, security architecture and operational controls. Turn each section into a page about the fictional station rather than reading it only for vocabulary. The short list lives on the reference desk.

Topic	Reading family	How to use it
Measurement and protection	IEEE C37.110, C57.13, C37.2; relevant IEC 60255 and IEC 61869 parts	Connect measurement performance, function definitions and equipment requirements to the actual application.
Equipment protection	IEEE C37.91, C37.113, C37.119 and equipment-specific guides	Develop application reasoning and test coverage, using the applicable editions.
Arc flash and workplace electrical safety	IEEE 1584; CSA Z462 for Canadian context; NFPA 70E where relevant	Distinguish calculation method from work-practice requirements. Verify project scope, edition and jurisdiction.
Digital substation	IEC 61850 and relevant IEC 62351 parts	Separate communication and data-model requirements from security requirements and device support.
OT cybersecurity	NIST SP 800-82 Rev. 3; ISA/IEC 62443	Build an OT risk assessment, architecture and recovery approach that respects physical-process constraints.
Reliability compliance	NERC PRC, CIP and, as needed, applicable MOD, TPL and FAC standards	Establish applicability, responsible entity, effective version and implementation dates before creating evidence.

9 · Laptop lab

The MSI is enough to start. Do not buy a relay yet.

Begin with a few modest virtual machines, a virtual firewall or router, a protocol client, server or simulator, packet capture, and version-controlled project files. Start without buying relays, switches or another computer.

Maintain two connected learning models: an electrical model of the fictional station and an isolated communications model. Do not claim that a software simulation establishes real relay timing or hardware interoperability. If a protocol implementation or license is unavailable, document its interface and use public captures or a tabletop exercise until actual testing is possible.

For power studies, use a legally available tool appropriate to the calculation. Previously reported school PSS/E access must be checked for current availability and permitted use. Choose one principal study tool initially. Commercial project needs can later determine ETAP, SKM, ASPEN, CAPE or another platform. Learn model assumptions and independent checks before collecting software packages.

Develop the COMTRADE analyzer incrementally: channel and time display; correct scaling; declared phasor and RMS algorithms; sequence components; digital timeline; then carefully defined impedance loops. Record sampling-rate changes, window delay, frequency assumptions, missing values and trigger and time semantics. Validate synthetic balanced, unbalanced and changing-frequency signals and at least one independently interpreted public event. An automated narrative must be traceable to evidence and must not invent fault causes.

10 · Portfolio

Nine pieces, and four stages of a skill.

P1 · Transformer application.
P2 · Automation and cyber boundary package v1.
P3 · Integrated fault and coordination study.
P4 · Year-1 campus protection and automation package.
P5 · Integrated studies package (short circuit, coordination, arc flash).
P6 · Bay design package.
P7 · Event investigation.
P8 · OT security package.
P9 · Capstone defence.

Every artifact includes purpose, input provenance, assumptions, method, independent checks, scenarios, results, limitations, revision history and review findings. Public portfolio copies must contain only material you are authorized to disclose.

Explain. Describe the mechanism and assumptions clearly.
Apply. Solve a new exercise and independently check it.
Deliver with review. Produce usable work and close a qualified reviewer’s findings.
Lead within scope. Show repeated sound decisions, handle exceptions and review others’ work within your authority and competence.

Progression is topic-specific. A strong event analyst can still be a beginner in transient stability. Self-review and automated checks help learning but do not replace independent technical review for client engineering.

11 · Offering services

Capability first. Authorization before marketing.

Begin by building capability and reviewed experience within authorized employment or project arrangements. The earliest prospective scope is likely commissioning planning, relay settings and test QA, event-analysis support, and OT asset and configuration documentation. Classify the actual engagement before offering it. Calling engineering “support” does not remove professional obligations.

In Ontario, a personal engineering licence and a firm’s Certificate of Authorization serve different purposes. PEO states that offering or providing professional engineering services to the public requires a Certificate of Authorization. Plan the appropriate Ontario registration, responsible professional oversight and business authorization before marketing engineering services. Registration elsewhere does not by itself establish Ontario practice authority.

Before independent delivery, have a defined scope, competence evidence, applicable authorization, technical review, suitable contractual and insurance arrangements, and approved access to tools and data. For employed side work, resolve employer conflict and outside-work requirements before accepting an engagement.

The eventual differentiator is practical: explain what a power system should do, why its protection operated, and how to secure and recover the digital systems that control it.

Sources · checked 6 October 2026

Verify versions when you book training.

Technical exercises, sequence, time estimates, deliverables and gates are recommendations tailored to this goal, not requirements asserted by these organizations.

03 / Read with a purpose

Reference desk.

Protection theory

Power System Relaying, 5th edition

Use the existing text in module order: foundations, transformer, overcurrent, distance, pilot protection and events. Use Blackburn & Domin for a second explanation.

Device implementation

GE T60, SEL-487E/787 and SIPROTEC 7UT manuals

For the reported 7.43 platform, match the 7.4x manual to actual hardware and options. Verify source mapping and the manufacturer’s restraint definitions. Use the SEL and Siemens instruction manuals for a stated firmware revision for the parallel settings basis.

OT security baseline

NIST SP 800-82 Rev. 3

Published OT security guidance. Start with architecture, operational constraints and recovery. Distinguish published guidance from draft revisions.

Protection learning

SEL ePROT 401

Optional structured theory from the plan. Substitute it for overlapping study blocks; do not stack it onto the full eight-hour week.

Reliability requirements

NERC protection & control standards

Learn the purpose of PRC-004, PRC-005 and PRC-027. Confirm current versions and facility applicability before using a requirement.

Ontario applicability

IESO enforcement dates

Use jurisdictional enforcement information alongside the relevant standard. A publication date alone does not establish applicability.

Last checked 2026-10-15 · official uwaterloo.ca outlines

UWaterloo MEng, Electric Power.

Applied; if admitted, the plan is the normal 3-year part-time pace. Anything Waterloo does not publish is marked not published. These nine are the preferred portfolio from the learning roadmap. Waterloo lets a student choose any 9 of 18 ECE 66xxPD courses; these are not prescribed by the university.

Online only, part-time
9 courses, 0.50 units each
Normally 3 years / 9 terms; maximum 5 years / 15 terms
Self-funded: MEng students do not receive financial assistance
Supported by Hydro One Networks Inc.; Power and Energy Systems Group
Part-time: max 1 course a term, or 2 with permission
Minimum 65% in each course and a 70% cumulative average
Complete the Graduate Academic Integrity Module
Fall 2026 domestic Ontario: $3,521.00 per course; incidental fees $46.25 a term
Spring 2026 domestic Ontario: $3,452.00 per course
Winter 2027 domestic Ontario: $3,521.00; out-of-province $4,194.00; international $5,349.00
Spring 2027 tuition: not published yet

ECE 6601PD textbooks, from the outline

Arrillaga and Watson, Computer Modeling of Electrical Power Systems, 2nd ed., 2001.
Hingorani and Gyugyi, Understanding FACTS, IEEE Press, 2000.
Arrillaga, High Voltage Direct Current Transmission, 2nd ed., IET, 1998.
ABB, Transmission and Distribution Reference Book, 5th ed., 1997.
BPA, EMTP Theory Book, 1986.
Kundur, Power System Stability and Control, McGraw-Hill, 1994.
Anderson, Power System Protection, IEEE, 1998.
Gómez-Expósito, Conejo and Cañizares, eds., Electric Energy Systems: Analysis and Operation, CRC, 2008.
Gross, Power System Analysis, 2nd ed., Wiley, 1986.
Yin et al., Unified Power Flow Controller Technology and Application, Elsevier, 2017.

ECE 6601PD · Fall 2027

Power System Components and Modeling

Claudio A. Cañizares · Wednesdays 2:00–4:50pm

Projects 40% (generator, then a line and load, both in MATLAB). Midterm 10% on Saturday 26 October at 10:00, take-home, some MATLAB. Final 50%, date not published. Weeks: generation plant 4, transformers 2, lines and cables 2, loads 2, HVDC 1, FACTS 1, then renewables and storage examples. Covers electromagnetic-transient and phasor models.

ECE 6613PD · Winter 2028

Power System Analysis

Claudio A. Cañizares · schedule not published

Projects 40% (IEEE 14-bus power flow and short circuit in PSAT and MATLAB; then stability in PSAT). Midterm assignment 10%. Final 50%, date not published. Topics run from a model review through power flow, short circuit, voltage, small-signal, transient and frequency stability.

ECE 6605PD · Spring 2027

Power System Protection

Coordinator: Sahar Azad

Protective equipment and techniques for feeders, transformers, generators and motors. The aim is a shorter fault and fewer customers affected.

ECE 6606PD · Winter 2027

Distribution System Engineering

Coordinator: Magdy Salama

Planning, design and operation: load forecasting, substations, primary and secondary systems, voltage drop, loss, regulation and capacitors.

ECE 6604PD · Fall 2027

Distributed Generation

Coordinator: Ramadan El-Shatshat

Generating technologies, power electronics, and the effect of DG on connection, protection, control, power quality, economics and regulation.

ECE 6603PD · Not scheduled Fall 2026–Spring 2028

Electromagnetic Compatibility and Power Quality

Coordinator: Ramadan El-Shatshat

Sags, interruptions, transients, flicker, harmonics, grounding, and mitigation including filters, SVC, DVR and UPQC. Includes DG effects on regulation, relaying, losses and islanding.

ECE 6616PD · Not scheduled Fall 2026–Spring 2028

Electric Safety and Grounding System Design

Not published

Safety for low, medium and high voltage, grounding design, and the management and human factors that decide whether a system is actually safe.

ECE 6617PD · Not scheduled Fall 2026–Spring 2028

Asset Management and Risk Assessment

Not published

Outage models, risk assessment, and asset-management examples for lines, generators and substations.

ECE 6610PD · Not scheduled Fall 2026–Spring 2028

Power Electronic Converters

Coordinator: Mehrdad Kazerani

Devices, AC–DC, DC–DC, DC–AC and AC–AC topologies, multi-level converters, control, snubbers, thermal design and simulation.