Thyssengas Netzauskunft

Publication of information according to Commission Regulation (EU) 2017/460 (NC TAR)

According to Section 30 of the network code on rules regarding harmonised transmission tariff structures for gas (Commission Regulation (EU) 2017/460) European transmission system operators have to publish several information on their websites. Here you can find an overview of these information.

  • You can download the 2022 table here
  • You can download the 2021 table here


Publication requirements according Commission Regulation (EU) 2017/460 (NC TAR)

(as of 2 June 2021)

Description

Information

Information to be published before the annual yearly capacity auction (Art. 29 NC TAR) 

Art. 29 (a)

information on firm standard capacity products (reserve prices, multiplier, seasonal factors,…)

Tariffs for firm standard capacity products:

for 2021

for 2022 

 

For the justification of the level of multipliers, we refer to BNetzA Decision BK9-20/612 ("MARGIT 2022")

Art. 29 (b)

information on interruptible standard capacity products (reserve prices, assessment of the probability of interruption)

Tariffs for interruptible standard capacity products:

for 2021

for 2022 


In attachment I of BNetzA Decision BK9-20/612 ("MARGIT 2022") the Federal Network Agency has specified the level of the discounts for interruptible capacity at interconnection points. The methodology to calculate these discounts is described in Section 6 of MARGIT 2022.


The methodology to calculate discounts for interruptible capacity at other than interconnections points, inter alia storage points, is specified in BNetzA Decision BK9-20/608 ("BEATE 2.0", section 3.2). Hereby, the probability of interruption is derived from the data of the last three gas years of the respective entry or exit point and is calulated as the ratio between the sum of interrupted capacity booked on an interruptible basis on each day to the sum of interruptible capacity marketed on these days. The probability of interruption is rounded up to full percentage and increased by a safety margin of 10% points for other than interconnection points in the L-gas network as well as 20% points for other than interconnection points in the H-gas network, which represents the forecast uncertainty. The applicable discount corresponds to the probability of interruption regardless of the product duration. This corresponds to the safety margins at interconnection points according to MARGIT 2022.


There has been no interruption at the points according to BEATE 2.0; the discount for interruptible capacity at these points amounts to 10% in the L-gas network and to 20% in the H-gas network.
For the discount for interruptible capacity in the calender year 2022 we refer to attachment I of MARGIT 2022.
The data to calculate the discounts have been published during the consultation.

 

Publication requirements according Commission Regulation (EU) 2017/460 (NC TAR)

(as of 2 December 2020)

Description

Information

Information to be published before the tariff period (Art. 30 NC TAR) 

Art. 30 (1a) i)

technical capacity at entry and exit points and associated assumptions

Not applicable (N/A)

Art. 30 (1a) ii)

forecasted contracted capacity at entry and exit points and associated assumptions

All used input parameters (especially capacity forecasts) are contained in the simplified tariff model.

Art. 30 (1a) iii)

the quantity and the direction of the gas flow for entry and exit points and associated assumptions, such as demand and supply scenarios for the gas flow under peak conditions

Not applicable (N/A)

Art. 30 (1a) iv)

the structural representation of the transmission network with an appropriate level of detail

Not applicable (N/A)

Art. 30 (1a) v)

additonal technical information about the transmission network, such as the length and the diameter of pipelines and the power of compressor stations

Not applicable (N/A)


Art. 30 (1b)(i)

the allowed or target revenue, or both, of the transmission system operator

Allowed revenue 2021:

178,211,417 €

Art.30 (1b) (ii)

the information related to changes in the revenue referred to in point (i) from one year to the next year

The change in the allowed revenue 2021 compared to the allowed revenue 2020 can be essentially explained by the increase of the deduction for the regulatory account. The cost base was adjusted according to the formula of the ARegV (see Annex 1 to ARegV). 

Art.30 (1b) (iii) (1)

types of assets included in the regulated asset base and their aggregated value

Types of regulated assets (see Annex 1 of GasNEV):

I.    General installations

II.  Gas container

III. Compressor stations

IV.Pipelines/ House connection pipelines

V.  Measuring, control and metering installations

VI. Remote control installations


Total regulated asset base of cost base year 2015:

459,420,433 €

Art.30 (1b) (iii) (2)

cost of capital and its calculation methodology

Cost of capital in the cost base year 2015: 43,979,914 €

The methodology of calculating the cost of capital are determined in sections 6-8 GasNEV.

Art.30 (1b) (iii) (3)

capital expenditures, including:


a) methodologies to determine the initial value of assets

The procurement and manufacturing costs of the assets are calculated according to section 255 HGB.

b) methodologies to re-evaluate the assets

There is no re-evaluation of assets foreseen in the German incentive regulation. 

c) explanations of the evolution of the value of the assets

The assets are depreciated on a linear basis in accordance with section 6 (5) GasNEV. The depreciation periods are set in Annex 1 GasNEV.

d) depreciation periods and amounts per asset type

Depreciation periods and amounts per asset type:


I. General installations 

3-70 years (no depreciation for land)

amount in cost base year 2015: 2,877,945 €


II. Gas container 

45-55 years

amount in cost base year 2015: 0 €


III. Compressor stations 

20-60 years

amount in cost base year 2015: 3,236,422 €


IV. Pipelines/ House connection pipelines 

30-65 years

amount in cost base year 2015: 13,408,238 €


V. Measuring, control and metering installations 

8-60 years

amount in cost base year 2015: 6,933,262 €


VI. Remote control installations 

15-20 years

amount in cost base year 2015: 0 €

Art.30 (1b) (iii) (4)

operational expenditures

Operational expenditures of cost base year 2015: 

95,167,718 €

Art.30 (1b) (iii) (5)

incentive mechanisms and efficiency targets

German transmission system operators are subject to the incentive regulation system. The incentive system  and the efficiency targets are set out in  §§ 12-16 ARegV. The revenue cap of a transmission system operator (TSO) that is determined for a regulatory period with a duration of 5 years is based on the costs incurred at the TSO in the base year (year 3 before the new regulatory period) and that were checked by the regulatory authority. Moreover, an efficiency benchmark is conducted between the TSO and, based on their cost and structure parameters, individual company efficiency values are calculated. Possible inefficiencies are to be rectified over the duration of a regulatory period. Furthermore, the regulatory authority calculates a general sector productivity factor that is consistently applied to all TSO.

The individual company efficiency value for the 3rd regulatory period (2018-2022) amounts to 100% for Thyssengas. The Federal Network Agency determined the general sector productivity factor for the 3rd regulatory period to 0,49%.

Art.30 (1b) (iii) (6)

inflation indices

The inflation index is yielded from the specifications of section 8 ARegV. The value VPIt in the formula of annex 1 ARegV for the revenue cap 2021 is set by the published value for 2019 of Statistisches Bundesamt and amounts to 105.3. The value of the base year (VPI0) in the formula of annex 1 ARegV is set by the published value for 2015 of Statistisches Bundesamt. The figure for the year 2015 is 100.

www.destatis.de

Art. 30 (1b) (iv)

the transmission services revenue

Transmission services revenue 2021: 171,129,006 €

Art. 30 (1b) (v)

the following ratios for the revenue referred to in point (iv):


(1) capacity-commodity split, meaning the breakdown between the revenue from capacity-based transmission tariffs and the revenue from commodity-based transmission tariffs

Capacity-commodity split in %: 100/0

(2) entry-exit split, meaning the breakdown between the revenue from capacity-based transmission tariffs at all entry points and the revenue from capacity-based transmission tariffs at all exit points

Entry-Exit-Split in the market area NCG in %:  32.8/67.2 (market area wide)

Entry-Exit-Split in the market area THE in %:   36.0/64.0 (market area wide)

(3) intra-system/cross-system split, meaning the breakdown between the revenue from intra-system network use at both entry points and exit points and the revenue from cross-system network use at both entry points and exit points calculated as set out in Article 5

Split in the market area NCG:

intra-system network use: 81.1 % (market area wide)

cross-system network use: 18.9 % (market area wide)

Split in the market area THE:

intra-system network use: 74.9 % (market area wide)

cross-system network use: 25.1 % (market area wide)

In connection with the consultation according to Art. 26 NC TAR the Federal Network Agency carried out a cost allocation test. The results including a valuation have been published on the website of the Federal Network Agency during the formal procedure of REGENT for the market areas NetConnect Germany (BK9-18/210-NCG), GASPOOL (BK9-18/611-GP) and Trading Hub Europe (BK9-19/610): 

Market area NCG  

Market area THE 

Art. 30 (1b) (vi)

where and to the extent that transmission system operator functions under a non-price cap regime, the following information related to the previous tariff period on regarding the reconciliation of the regulatory account:


(1) the actually obtained revenue, the under-or over-recovery of the allowed revenue and the part thereof attributed to the regulatory account and, if applicable, sub-accounts within such regulatory account

Actual obtained revenue from transmission and non-transmission services 2019: 184,125,812 €

Aggregated balance of the regulatory account of the closed financial year 2019: -18.766.888 €

(2) the reconciliation period and the incentive mechanisms implemented

Reconciliation of the regulatory account for the concluded business year 2019 is determined in the year 2020 and it will be reconciled in equal instalments – including interest payments – over the subsequent 3 calendar years.

Incentive mechanisms specifically for the regulatory account do not exist in the German regulatory system.

Art. 30 (1b) (vii)

the intended use of the auction premium

Auction revenues are booked on the regulatory account in accordance with Article 5 ARegV. This transaction thus develops a tariff-reducing effect in the years in which the regulatory account is reconciled.


Art. 30 (1c)

the following information on transmission and non-transmission tariffs, accompanied by the relevant information related to their derivation:


Art.30 (1c) (i)

where applied, commodity-based transmission tariffs related to in Article 4(3)

Not applicable (N/A)

Art.30 (1c) (ii)

where applied, non-transmission tariffs for non-transmission services referred to in Article 4(4)

Derivation of Biogas levy

In accordance with number 6 BNetzA decision BK9-18/610-NCG (“REGENT-NCG”) and BK9-19/619 ("REGENT 2021") the Biogas levy according to section 20b GasNEV is classified as non-transmission service. The derivation of Biogas levy is described in section 7 of the Cooperation Agreement between the Operators of Gas Supply Networks in Germany as of 31 March 2020 (valid from 1 October 2020). According to this, all biogas-costs of 2021 in Germany in the amount of 191,593,308 € are divided by all forecasted contracted capacity for TSO exit points to DSO and end consumers (without consideration of multipliers or seasonal factors) of 2021 in the amount of 306,560,401 (kWh/h)/a. Hence, the biogas levy is 0.6250 €/(kWh/h)/a.


Derivation of Market area conversion levy

In accordance with number 5 BNetzA decision BK9-18/610-NCG (“REGENT-NCG”) and BK9-19/610 ("REGENT 2021") the Market area conversion levy according to section 19a(1) Energy Industry Act is classified as non-transmission service. The derivation of Market area conversion levy is described in section 10 of the Cooperation Agreement between the Operators of Gas Supply Networks in Germany as of 31 March 2020 (valid from 1 October 2020). According to this, all market conversion costs of 2021 in the amount of  223,527,688 € are divided by all forecasted contracted capacity for TSO exit points to DSO and end consumers (without consideration of multipliers or seasonal factors) of 2021 in the amount of 306,560,401  (kWh/h)/a. Hence, the market area conversion levy is 0.7291 €/(kWh/h)/a.


Derivation of tariffs for meter operation and meter reading

In accordance with number 7 BNetzA decision BK9-18/610-NCG ("REGENT-NCG") and BK9-19/610 ("REGENT 2021") meter operation and metering is classified as non-transmission service. With regard to § 15 Section 7 GasNEV Thyssengas raises tariffs for meter operation and metering at exit points at which Thyssengas provides the respective service. According to the respective service the tariffs for meter operation and metering depend on Thyssengas being or not being the owner of the measuring station (meter operation)  as well as the measuring station being RLM od SLP (metering). They are published as annex to the price sheet on the Thyssengas website.

Thyssengas GmbH Price Sheet for Shippers and Downstream Network Operators applicable from 1 January 2021 (published 6 November 2020)

Art.30 (1c) (iii)

the reference prices and other prices applicable at points other than those referred to in Article 29

Within its decision REGENT-NCG and REGENT 2021 the Federal Network Agency has determined the application of a postage stamp for the market area NetConnect Germany (NCG) and Trading Hub Europe (THE). Hereafter, the revenues from transmission services are to be divided by the forecasted capacities at all entry and exit points for the respective calendar year.

Thyssengas GmbH Price Sheet for Shippers and Downstream Network Operators applicable from 1 January 2021 (published 6 November 2020)

Art.30 (2)

In addition, the following information shall be published with regard to transmission tariffs:


Art. 30 (2a) (i)

an explanation of the following: the difference in the level of transmission tariffs for the same type of transmission service applicable for the prevailing tariff period and for the tariff period for which the information is published

In the market area NCG, the reference price will be reduced by 30 ct/(kWh/h)/a in 2021 compared to 2020. This change is based on regular tariff adjustments taking into account changes in the input parameters allowed revenues and forecasts of contracted capacity of the transmission system operators involved. With the launch of the market area Trading Hub Europe (THE) on 1 October 2021, the reference price will increase slightly by 3 ct/(kWh/h)/a compared to the NCG reference price. In the past, the reference price in the market area NCG was higher than the reference price in the market area GASPOOL.  In addition, the capacity forecasts had to be adjusted to reflect, among other things, the omission of the former market area connection points between the market areas NCG and GASPOOL and the changed discounts for interruptible capacity, DZK and bFZK.

Art.30 (2a) (ii)

an explanation of the following: the estimated difference in the level of transmission tariffs for the same type of transmission service applicable for the tariff period for which the information is published and for each tariff period within the remainder of the regulatory period

On the basis of the data provided by the transmission system operators the Federal Network Agency has forecasted the development of the tariffs for the third regulatory period and has published the results in annex 5 of decision REGENT 2021. Hereafter, the tariffs will slightly increase in the years 2022 to 2023.

Further information can be found on the website of the Federal Network Agency.

Art. 30 (2)(b)

at least a simplified tariff model, updated regularly, accompanied by the explanation of how to use it, enabling network users to calculate the transmission tariffs applicable for the prevailing tariff period and to estimate their possible evolution beyond such tariff period

Simplified tariff model according to Commission Regulation (EU) 2017/460 (NC TAR)

Art.30 (3)

for the points excluded from the definition of relevant points referred to in point 3.2(1)(a) of Annex 1 to Regulation (EC) No 715/2009, the information on the amount of forecasted contracted capacity and the forecasted quantity of the gas flow shall be published as set out in point 3.2(2) of Annex 1 to Regulation (EC) No 715/2009

Forecasted contracted capacity at points not being relevant according to point 3.2(1)(a) of Annex 1 to Regulation (EC) No 715/2009: 23,099,101 kWh/h.

The forecasted quantity of the gas flow is not relevant for the tariff determination.