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The Nordic Capacity Calculation Methodology (CCM) project
Stakeholder Group
Copenhagen Towers
August 22, 2019
15:00 – 15:30AOB9
14:30 – 15:00KPIs, Go-live criteria8
14:00 – 14:30Coffee break7
13:00 – 14:00Nordic RSC visit 6
12:00 – 13:00Lunch5
10:30 – 12:00FB, and FB intuitive simulation results 4
10:15 – 10:30Coffee break3
09:45 – 10:15Status update, and short walk-through of updated DA/ID CCM 2
09:30 – 09:45Introduction and welcome1
Table of Contents
15:00 – 15:30AOB9
14:30 – 15:00KPIs, Go-live criteria8
14:00 – 14:30Coffee break7
13:00 – 14:00Nordic RSC visit 6
12:00 – 13:00Lunch5
10:30 – 12:00FB, and FB intuitive simulation results 4
10:15 – 10:30Coffee break3
09:45 – 10:15Status update, and short walk-through of updated DA/ID CCM 2
09:30 – 09:45Introduction and welcome1
Table of Contents
Stakeholder involvement: reminder
❖Stakeholder Group (SHG)✓Group with nominated members from industry
and NRAs✓Detailed discussions and exchanges
❖Stakeholder Forum (SHF)✓Open for all stakeholders ✓Broader information forums
❖Stakeholder Newsletter
❖Stakeholder Information Platform (SHIP)✓Web platform, hosted by the Nordic RSC, for
information exchange and discussion✓Open for all stakeholders
CCM project and Nordic RSC: reminder
CCM project
-
CCM methodology development
-
CCM implementation
(amongst others)
Indicative timeline
2018 20222018 2019 2020 2021 2022
NRA: DA/IDCCM approval
Jul 16
NRA: RfA (DA/ID CCM)
Dec 20
NRA: amended DA/IDCCM approval
Aug 20
TSO: Amended DA/IDCCM submission
Jun 20
Earliest Nordic DA CCM and intermediateID CCM go-live
Jul 1
TSO: Submission of FCACCM proposal to NRAs
Jan 16
NRA: FCA CCMACER referal
May 8
ACER: FCA CCMdecision
Nov 8
Public //run quality criteria are
met (industrial tool), and all TSO
input data available
Jun 30
Go-live criteria are met
Jul 1
15:00 – 15:30AOB9
14:30 – 15:00KPIs, Go-live criteria8
14:00 – 14:30Coffee break7
13:00 – 14:00Nordic RSC visit 6
12:00 – 13:00Lunch5
10:30 – 12:00FB, and FB intuitive simulation results 4
10:15 – 10:30Coffee break3
09:45 – 10:15Status update, and short walk-through of updated DA/ID CCM 2
09:30 – 09:45Introduction and welcome1
Table of Contents
Amended DA/ID CCM
❖Nordic NRAs approved the Nordic DA/ID CCM in July 2018
❖The NRAs of the Nordic CCR issued an RfA in December 2018
✓The amendment applies for Energinet, Fingrid, and Svenska kraftnät
❖The TSOs of the Nordic CCR amended the DA/ID CCM; a public consultation was held from April 12 to May 20, 2019
❖TSOs submitted the amended DA/ID CCM to the NRAs of the Nordic CCR on June 20 2019
2018 20222018 2019 2020 2021 2022
NRA: DA/IDCCM approval
Jul 16
NRA: RfA (DA/ID CCM)
Dec 20
NRA: amended DA/IDCCM approval
Aug 20
TSO: Amended DA/IDCCM submission
Jun 20
Earliest Nordic DA CCM and intermediateID CCM go-live
Jul 1
TSO: Submission of FCACCM proposal to NRAs
Jan 16
NRA: FCA CCMACER referal
May 8
ACER: FCA CCMdecision
Nov 8
Public //run quality criteria are
met (industrial tool), and all TSO
input data available
Jun 30
Go-live criteria are met
Jul 1
Amended DA/ID CCMResults from the public consultation
❖6 responses have been received
❖EFET provided generic responses, not linked to the DSA / RfA
❖The response from Finnish Energy and Swedenergy is identical. They wonder a.o. what’s the legal status of the amendments on Statnett and Kraftnät Åland?
❖Energi Norge remarks that the FB implementation has become even more challenging
❖Statnett expresses concerns linked to compliancy, European processes, economic efficiency, and operational security
❖Statkraft hopes that a common approach by only 3 of the 4 Nordic TSO will not have any negative impact for the implementation of CCM
1 EFET
2 Finnish Energy
3 Energi Norge
4 Statnett
5 Statkraft
6 Swedenergy
Amended DA/ID CCMArticles amended
❖Whereas
❖Article 4 on methodology for determining operational security limits
❖Article 31 Capacity calculation process
❖Article 32 Publication and Implementation
AmendedDA/ID CCM
Amended DA/ID CCMArticle 32 - Implementation
CCC responsible for common dynamic grid model and dynamic security analysis
Each TSO responsible for dynamic grid model and dynamic security analysis
LT CCM
2018 20222018 2019 2020 2021 2022
NRA: DA/IDCCM approval
Jul 16
NRA: RfA (DA/ID CCM)
Dec 20
NRA: amended DA/IDCCM approval
Aug 20
TSO: Amended DA/IDCCM submission
Jun 20
Earliest Nordic DA CCM and intermediateID CCM go-live
Jul 1
TSO: Submission of FCACCM proposal to NRAs
Jan 16
NRA: FCA CCMACER referal
May 8
ACER: FCA CCMdecision
Nov 8
Public //run quality criteria are
met (industrial tool), and all TSO
input data available
Jun 30
Go-live criteria are met
Jul 1
❖Nordic TSOs submitted their LT CCM proposal to the NRAs on Jan 16, 2019
❖Nordic NRAs referred the LT CCM proposal to ACER on May 8
❖ACER has 6 months time to take a decision on the Nordic LT CCM
15:00 – 15:30AOB9
14:30 – 15:00KPIs, Go-live criteria8
14:00 – 14:30Coffee break7
13:00 – 14:00Nordic RSC visit 6
12:00 – 13:00Lunch5
10:30 – 12:00FB, and FB intuitive simulation results 4
10:15 – 10:30Coffee break3
09:45 – 10:15Status update, and short walk-through of updated DA/ID CCM 2
09:30 – 09:45Introduction and welcome1
Table of Contents
15:00 – 15:30AOB9
14:30 – 15:00KPIs, Go-live criteria8
14:00 – 14:30Coffee break7
13:00 – 14:00Nordic RSC visit 6
12:00 – 13:00Lunch5
10:30 – 12:00FB, and FB intuitive simulation results 4
10:15 – 10:30Coffee break3
09:45 – 10:15Status update, and short walk-through of updated DA/ID CCM 2
09:30 – 09:45Introduction and welcome1
Table of Contents
"Non-intuitive" flows
❖A non intuitive flow is a flow from a high price to a low price BZ
❖Non intuitive flows are a result of the FB market optimization
❖Non-intuitive flows occur to relieve congestions on constrained grid elements
❖Non-intuitive flows occur when the welfare economic cost of a non-intuitive flow is smaller than the welfare economic benefit of relieving a congestion
❖By relieving capacity on congested grid elements, non-intuitive flows contribute positively to the overall market efficiency, and thus generate a market wide efficiency gain
❖In equilibrium, the marginal value of all trades are equal
❖Non intuitive flows are applied in existing nodal price systems, and in the current Nordic market by enforcing the power to flow in a certain direction (NO1-NO3, and NO5-NO3)
Welfare optimum
❖𝑻𝒉𝒆 𝒇𝒊𝒓𝒔𝒕 𝒐𝒓𝒅𝒆𝒓 𝒄𝒐𝒏𝒅𝒊𝒕𝒊𝒐𝒏 𝒇𝒐𝒓 𝒂 𝒈𝒍𝒐𝒃𝒂𝒍 𝒘𝒆𝒍𝒇𝒂𝒓𝒆 𝒐𝒑𝒕𝒊𝒎𝒖𝒎 𝒊𝒔:
𝑃𝑖 = 𝜆 − σ𝑛 𝜌𝑛 𝑃𝑇𝐷𝐹𝑛𝑖 𝑃𝑖 = The price/marginal value of power in BZ i
𝜆 = The marginal value of power in the slack node (not the system price)
𝜌𝑛 = 𝑆ℎ𝑎𝑑𝑜𝑤 𝑝𝑟𝑖𝑐𝑒 𝑜𝑓 𝑡ℎ𝑒 𝑐𝑜𝑛𝑠𝑡𝑟𝑎𝑖𝑛𝑖𝑛𝑔 𝑔𝑟𝑖𝑑 𝑒𝑙𝑒𝑚𝑒𝑛𝑡 𝑛
𝑃𝑇𝐷𝐹𝑛𝑖 = 𝑇ℎ𝑒 𝑃𝑇𝐷𝐹 𝑡𝑜 𝑡ℎ𝑒 𝑠𝑙𝑎𝑐𝑘 𝑓𝑜𝑟 𝐵𝑍𝑖 𝑜𝑛 𝐶𝑁𝐸 𝑛
❖The 𝒎𝒂𝒓𝒈𝒊𝒏𝒂𝒍 𝒗𝒂𝒍𝒖𝒆 𝒐𝒇 𝒂 𝒃𝒊𝒍𝒂𝒕𝒆𝒓𝒂𝒍 𝒕𝒓𝒂𝒅𝒆 𝒇𝒓𝒐𝒎 𝑩𝒁𝒊 𝒕𝒐 𝑩𝒁𝒋can be derived from the f.o.c.:
𝜌𝑘 ≥ 0 𝑎𝑛𝑑 𝜌𝑘 σ𝑖𝑁𝑃𝑖 ∗ 𝑃𝑇𝐷𝐹𝑘𝑖 − 𝑅𝐴𝑀𝑘 = 0
𝑃𝑗−𝑃𝑖
σ𝑛 𝛼𝑛 𝑃𝑇𝐷𝐹𝑛𝑖−𝑃𝑇𝐷𝐹𝑛
𝑗 = σ𝑘 𝜌𝑘 𝛼𝑛 =𝜌𝑛
σ𝑘 𝜌𝑛
𝑘 = 𝑡ℎ𝑒 𝑠𝑒𝑡 𝑜𝑓 𝑎𝑙𝑙 𝑙𝑖𝑚𝑖𝑡𝑖𝑛𝑔 𝑔𝑟𝑖𝑑 𝑒𝑙𝑒𝑚𝑒𝑛𝑡𝑠, 𝑛 ∈ 𝑘
➢ Non-intuitive flows are non-intuitive, not non-efficient
Example - Non intuitive flow
A
B C
Line (CNE) Max flow Min flow PTDF A PTDF B PTDF C
A -> B (CNE 1) 800 MW -800 MW 33 % - 33 % 0
B -> C (CNE 2) 1400 MW -1400 MW 33 % 67 % 0
A -> C (CNE 3) 1000 MW -1000 MW 67 % 33 % 0
Line Max NTC Min NTC
A -> B 500 MW -500 MW
B -> C 1000 MW -1000 MW
A -> C 400 MW -400 MW
FB and CNTC market solution
FB: B-A congestedNon-intuitive flow A-CGlobal optimum
NTC: All lines congested
11448
Intuitive FB and CNTC market solution
FB: B-A congested
Intuitive flow solution
NTC: All lines congested
10836
5% lower benefit from FB due to the non-intuitive constraint
Non-intuitive flows – what and why?
❖Non-intuitive flows are flows from a high price area to a low price area
❖They occur because the non-intuitive flow relieve a congested grid element which limits a more beneficial trade
❖Hence the socio-economic cost of a non-intuitive trade is smaller than the gain
Simulations
❖We have simulated two cases:
✓ FB original: the proposed FB-method
✓ FB intuitive patch: a "soft patch", ensuring flows only from a group of low prices to a group of highprices. Within the low-price group, you still may find the non-intuitive flows from a high-price zone to a low-price zone
❖Both cases are compared to NTC-method
Data for the analysis
❖11 weeks of data
✓ 76 days
✓ 1 day excluded from the analysis
Results: Total welfare gain
❖FB original gave a welfare gain of approx. 1.5 MEUR more than FB using the intuitive-patch
❖The figure shows cumulated socioeconomic welfare gains with FB compared to NTC for both cases
This figure is reported in the newsletter, but we discovered that the congestion rent is not correctly computed.
The components in welfare gain
❖Consumer and producer surplus is reduced when non-intuitive flows are not allowed
❖Congestion rent values are wrong due to internal script in the CCM-project.✓ Data on consumer, producer surplus and prices come from Euphemia
Summary
❖The table below summarizes the results for the 11 weeks analyzed
❖ Consumers and producers both loose due to more congestions and lager price spread
15:00 – 15:30AOB9
14:30 – 15:00KPIs, Go-live criteria8
14:00 – 14:30Coffee break7
13:00 – 14:00Nordic RSC visit 6
12:00 – 13:00Lunch5
10:30 – 12:00FB, and FB intuitive simulation results 4
10:15 – 10:30Coffee break3
09:45 – 10:15Status update, and short walk-through of updated DA/ID CCM 2
09:30 – 09:45Introduction and welcome1
Table of Contents
15:00 – 15:30AOB9
14:30 – 15:00KPIs, Go-live criteria8
14:00 – 14:30Coffee break7
13:00 – 14:00Nordic RSC visit 6
12:00 – 13:00Lunch5
10:30 – 12:00FB, and FB intuitive simulation results 4
10:15 – 10:30Coffee break3
09:45 – 10:15Status update, and short walk-through of updated DA/ID CCM 2
09:30 – 09:45Introduction and welcome1
Table of Contents
Nordic RSC
Jens Møller BirkebækNordic RSC manager
CCM Stakeholder Group meeting August 22nd, 2019
Nordic Regional Security Coordination
Background
1. Enhancing Nordic Power System Cooperation
2. European Network Code implementation
Purpose
Support the Nordic TSO´s in two key focus areas:
1. Maintain Security of Supply in the Nordic Area
2. Optimize the availability of the Nordic Power Grid
Tasks
Regional Operational Planning and Coordination in time horizons from year to intraday.
Digitalization of the Power SystemThe Common Grid Model is the basis
Nordic RSC – a journey and continous development
Flow Based capacity calculation – an interlinked TSO/RSC procesTSO
sN
ord
ic R
SC
Nordic CGMAservice
D-2 CGM
1. TSO´s deliver
D-2 forecast
data
2. Nordic RSC calculate a
Nordic CGMA
(D-2 netpositions pr.
bidding zone)
3. TSOs develop the D-2
IGM based on Nordic CGMA
4.TSO´s provide
D-2 IGM and
additional data
to the Nordic
RSC
5. Nordic RSC create
the Nordic D-2 CGM
and security analysis
6. Nordic RSC
Flow Based
domain data
Flow Based
calculation
7. TSOs validate
the calculations
8. Nordic RSC provide
common Nordic data to
power exchanges
8/22/2019
37
Nordic RSC – one of five European RSC´s
IT Application from GE Grid Solutions
NorCap Project
NorCap project- Who is involved?
Project Management
IT ApplicationMethodology &
processes
NORDIC RSC
GE GRID SOLUTIONNORDIC TSOs
Coordinated GRID Model(CGM)
Flowbased and Coordinated NTC
(FB & CNTC)
Coordinated Security Analysis
(CSA)
Market information tool
Integration to NEMOs
NORCAP IT APPLICATION
NorCap project- What is scope?
Day ahead and
Intraday
NorCap project- The high-level process?
Intraday and Day ahead processes
IGM
CGM
Flowbased calculation Capacity/
domain validation
MIT
NEMOsIGM
IGM
CNTC calculation
FRM
TRMCSA
Out of scope
NorCap scope
IGM
Release
capacities
Procurement (Tender)
Proof of Concept
Design Development Installation
CGM & FLOWBASED
Design Development Installation
COORDINATED NTC
TODAY
Market information tool
Integration to NEMOs
NorCap project- What is the plan?
FRMNext release
Handled in parallel
Thank You
15:00 – 15:30AOB9
14:30 – 15:00KPIs, Go-live criteria8
14:00 – 14:30Coffee break7
13:00 – 14:00Nordic RSC visit 6
12:00 – 13:00Lunch5
10:30 – 12:00FB, and FB intuitive simulation results 4
10:15 – 10:30Coffee break3
09:45 – 10:15Status update, and short walk-through of updated DA/ID CCM 2
09:30 – 09:45Introduction and welcome1
Table of Contents
15:00 – 15:30AOB9
14:30 – 15:00KPIs, Go-live criteria8
14:00 – 14:30Coffee break7
13:00 – 14:00Nordic RSC visit 6
12:00 – 13:00Lunch5
10:30 – 12:00FB, and FB intuitive simulation results 4
10:15 – 10:30Coffee break3
09:45 – 10:15Status update, and short walk-through of updated DA/ID CCM 2
09:30 – 09:45Introduction and welcome1
Table of Contents
KPIs for FB Go-live, background
Background:• CACM enforces 6 months parallel run
• Nordic CCM has extended the period to 12 months, and stated that before the parallel run can start, the following has to be met:
• Parallel run is scheduled to start 2020-06-30
KPIs for a go-live of the FB approach have been specified, in dialogue with NRAs and stakeholders.
KPI dialogue
•Nordic CCM project have drafted an initial attempt to define KPIs, as a starting point for a dialogue with Stakeholders & NRAs
Draft KPI document – 3 categories
1. FB capacity calculation process‒ Timely data delivery and robust processes
‒ TSOs & CCC commited to new capacity calculation process
‒ Integrations implemented (TSOs, CCC, MIT, NEMOs)
2. FB capacity calculation results‒ Timely and robust delivery of FB domains, with additional quantities
‒ ”Correctness” of FB domain
3. FB capacity allocation results‒ Timely and robust delivery of market results using FB constraints
‒ Market welfare is increased, compared to NTC
Proposed GO/NOGO criteria
▪All KPIs must be met fully in the last month of parallel runs (month 12)
▪If not met, the parallel run is extended until all KPIs are met for 1 month duration
Question: Who decides whether all KPIs are met?- NRAs, TSOs, Stakeholders, jointly?
15:00 – 15:30AOB9
14:30 – 15:00KPIs, Go-live criteria8
14:00 – 14:30Coffee break7
13:00 – 14:00Nordic RSC visit 6
12:00 – 13:00Lunch5
10:30 – 12:00FB, and FB intuitive simulation results 4
10:15 – 10:30Coffee break3
09:45 – 10:15Status update, and short walk-through of updated DA/ID CCM 2
09:30 – 09:45Introduction and welcome1
Table of Contents
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