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 table 2019 here
Publication requirements according Commission Regulation (EU) 2017/460 (NC TAR)
(as of 30 May 2018)
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 2018
for 2019


For the justification of the level of multipliers, we refer to BNetzA Decision BK9-14/608.
Art. 29 (b) information on interruptible standard capacity products (reserve prices, assessment of the probability of interruption) Tariffs for interruptible standard capacity products:
for 2018
for 2019

Regarding the probability of an interruption we refer to BNetzA Decision BK9-14/608 which sets out the methodology to calculate discounts for interruptible capacities to be used as an estimation of the probability of an interruption. The data necessary for calculating the discount is available
- on the ENTSOG Transparency Platform:
https://transparency.entsog.eu/
- für alle Punkte, an denen der Abschlag größer als 10% ist, im folgenden Dokument:
Discount interruptible capacity valid from 01.01.2019
Publication requirements according Commission Regulation (EU) 2017/460 (NC TAR)
(as of 30 November 2018)
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 Forecasted contracted entry capacity: 10,106,109 kWh/h
Forecasted contracted exit capacity at storages: 500,000 kWh/h
Forecasted contracted exit capacity at other points: 25,308,320 kWh/h
Assumptions: contracted capacities as well as forecasted contracted capacities, capacities are weighted according to the decision BEATE (decision BK9-14/608 of the Federal Network Agency)
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) additional 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 2019:
176,760,270 €
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 2019 compared to the allowed revenue 2018 can be essentially explained by the increase of the permanently non-influencable costs. 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 2019 is set by the published value for 2017 of Statistisches Bundesamt and amounts to 109,3. 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 106,9.
https://www.destatis.de
Art. 30 (1b) (iv) the transmission services revenue Transmission services revenue 2019: 172,432,946 €
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 %: 19/81
(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 Not applicable in 2019 (N/A)
Cross-border-domestic split will be determined in conjunction with Art. 26 NC TAR consultation
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 2017: 224,465,392 €
Aggregated balance of the regulatory account of the closed financial year 2017: -9,597,090 €
(2) the reconciliation period and the incentive mechanisms implemented Reconciliation of the regulatory account for the concluded business year 2016 is determined in the year 2017 and it will be reconciled in equal instalments – including interest payments – over the subsequent 5 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 According to Article 13(4) Gas Network Access Ordinance (GasNZV) 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 BK9-17/609 (“INKA”) 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 29 March 2018 (valid from 1 October 2018). According to this, all biogas-costs of 2019 in Germany in the amount of 202,994,689.14 € are divided by all forecasted contracted capacity for TSO exit points to DSO and end consumers (without consideration of multipliers or seasonal factors) of 2019 in the amount of 306,671,765.07 (kWh/h)/a. Hence, the biogas levy is 0.66193 €/(kWh/h)/a.

Derivation of Market area conversion levy
In accordance with number 6 BNetzA decision BK9-17/609 (“INKA”) 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 29 March 2018 (valid from 1 October 2018). According to this, all market conversion costs of 2019 in the amount of 132,257,041.18 € are divided by all forecasted contracted capacity for TSO exit points (including IP and storage exit points, but without consideration of multipliers or seasonal factors) of 2019 in the amount of 415,797,340.89 (kWh/h)/a. Hence, the market area conversion levy is 0.3181 €/(kWh/h)/a.

Derivation of tariffs for meter operation and meter reading
Section 6 of the decision of the Federal Network Agency (BK9-17/609, decision "INKA") classifies meter operation and meter reading as system services according to § 20b GasNEV. With regard to § 15 Section 7 GasNEV Thyssengas raises tariffs for meter operation and meter reading at exit points at which Thyssengas provides the respective service. The derivation of the tariffs for meter operation and meter reading is based on the costs for providing this service as well as the forecasted contracted capacities at the respective exit points. The tariffs are capacity depending and 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 (meter reading). They are published in the price sheet on the Thyssengas website.
Price Sheet Shippers/Downstream Network Operators
applicable from 1 January 2018
Art.30 (1c) (iii) the reference prices and other prices applicable at points other than those referred to in Article 29 Price Sheet Shippers/Downstream Network Operators
applicable from 1 January 2018
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 The change of tariffs from 2018 to 2019 essentially results from the adjustment of the revenue cap; the forecasted capacities remain largely unchanged.
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 It is currently impossible to make a valid estimation about what reference price method will be applicable for tariff calculation in the years 2020 ff. Correspondingly, no prognostic statements can be made regarding tariff development in the years 2020-2022.
In this matter we therefore refer to the final consultation according to Article 26 of the Tariff Network Code, which is carried out according to the decision "INKA" (BK9-17/609) by the Federal Network Agency. 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: 23,267,889 kWh/h.
The forecasted quantity of the gas flow is not relevant for the tariff determination.