Financial highlights of the PGNiG Group in 2017–2019 [PLN m]
 PGNiG Group
2019
2018
2017
2019/2018 change (%)
2019/2018 change
Revenue
42,023
41,234
35,685
2%
789
Total operating expenses
(39,575)
(36,839)
(31,775)
7%
(2,736)
Operating profit before interest, taxes, depreciation and amortisation (EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion)
5,504
7,115
6,579
(23%)
(1,611)
Depreciation and amortisation expense
(3,056)
(2,720)
(2,669)
12%
(336)
Operating profit
2,448
4,395
3,910
(44%)
(1,947)
Profit before tax
2,159
4,502
3,922
(52%)
(2,343)
Net profit
1,371
3,209
2,921
(57%)
(1,838)
Net cash from operating activities
4,938
5,814
4,816
(15%)
(876)
Net cash from investing activities
(6,152)
(4,704)
(3,863)
31%
(1,448)
Net cash from financing activities
327
237
(4,204)
38%
90
Net increase/(decrease) in cash and cash equivalents
(887)
1,347
(3,251)
(166%)
(2,234)
           

 

Dec 31 2019
Dec 31 2018
Dec 31 2017
2019/2018 change (%)
2019/2018 change
Total assets
59,185
53,271
48,203
11%
5,914
Non-current assets
43,939
38,898
36,364
13%
5,041
Current assets, including
15,246
14,373
11,839
6%
873
Inventories
4,042
3,364
2,748
20%
678
Total equity and liabilities
59,185
53,271
48,203
11%
5,914
Total equity
38,107
36,632
33,627
4%
1,475
Total non-current liabilities
10,378
7,255
7,004
43%
3,123
Total current liabilities
10,700
9,384
7,572
14%
1,316
Total liabilities
21,078
16,639
14,576
27%
4,439

Discussion of the PGNiG Group’s consolidated statement of profit or loss

Revenue

Revenue in 2018–2019 by business segment [%]

G: stable revenue from sale of heat, with average temperatures up 0.6°C yoy, and heat sales volumes down -3%; revenue from sale of electricity generated by the segment up +25% (PLN +190m) yoy, with stable sales volumes.

D: gas distribution volumes down -217 mcm (-2%) yoy; revenue from distribution services down -5% (PLN -206m) yoy, with the distribution tariff prices lower by -5%

E&P: revenue from sale of gas down PLN -1,450m (-32%) yoy, with sales volumes lower by -3% (-127 mcm); revenue from sale of crude oil and condensate down PLN -442m (-17%) yoy, with sales volumes down -14% (-200 thousand tonnes)

T&S: revenue from sale of gas up 3% (PLN +787m) yoy on a 6% increase in gas volumes sold to non-PGNiG Group customers and a +2.5% rise in the retail tariff prices

 

Operating expenses

Operating expenses in 2019 [%]

Cost of 10 dry wells and seismic surveys totalled PLN -259m in 2019 vs PLN -687m (31 dry wells) in 2018.

Effect of a PLN -305m write-down on gas inventories recognised in 2019 vs a PLN -21m write-down on gas inventories in 2018.

Effect of impairment losses on non-current assets: PLN -400m in 2019 vs PLN +224m reversal in 2018.

Depreciation of PLN -3,056m in 2019, PLN -347m in Norway.

Cost of gas up +7% yoy (PLN +1,745m)

Other raw materials and consumables up by PLN 458m (+18% yoy), including PLN 332m in electricity for trading purposes (+29% yoy)

Employee benefits expense 10% up (PLN +297m) yoy, driven mainly by higher employee benefits in the Distribution segment.

 

EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion

Change in EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion in 2018–2019 [PLN m]

 

 

Change in adjusted EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion in 2018–2019 [PLN m]

 

 

Net finance costs and net profit/loss

Net finance costs amounted to PLN -54m in 2019, and included mainly interest on debt (PLN -48m) and interest on lease liabilities (PLN -69m).

After profit/loss on equity-accounted investees of PLN -235m (of which approx. PLN -239m is impact of the equity valuation method on interests in PGG on the PGNiG Group consolidated net result for 2019) and tax expense of PLN -788m, the Group’s net profit for 2019 was at PLN 1,371m, down by PLN -1,838m year on year.

For detailed notes on finance income and costs (Note 3.4) equity-accounted investees (Note 2.4) and income tax (Note 4.1), see the consolidated financial statements of the PGNiG Group for 2019.

Overview of segment results

Change in EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion: 2018 vs 2019 [PLN m]

 

 

EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion in 2019 by business segment [PLN m]

 

Segment performance:

Explorations&Production
Trade&Storage
Distribution
Generation

Fluctuations in financial performance

The sale, distribution and storage of gas fuels, as well as cogeneration of heat and electricity, which, in addition to hydrocarbon exploration and production, constitute the principal business of the Group, are subject to significant seasonal fluctuations.

Revenue from sale of natural gas and heat in the winter season (Q1 and Q4) is substantially higher than in summer (Q2 and Q3). This is due to the seasonal changes in weather conditions in Poland, and the extent of the fluctuations is determined by temperatures – low in winter and higher in summer. Revenue from gas and heat sales is subject to much greater seasonal changes in the case of households, where gas and heat are used for heating, than in the case of industrial customers.

To ensure uninterrupted gas supplies in periods of peak demand and for reasons of security of the supplies, the underground gas storage facilities must be restocked in summer, and higher transmission and distribution capacities must be reserved for the winter season.

The performance of individual segments is also subject to significant fluctuations driven by changes in product prices. Moreover, the performance of the Exploration and Production segment reflects changes in hydrocarbon production profiles.

Fluctuations in PGNiG Group’s revenue in 2018–2019  [PLN m]

Fluctuations in PGNiG Group’s EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion in 2018–2019  [PLN m]

 

Quarterly EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion and adjusted EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion by operating segment in 2019 
2019
PLNm
PGNiG Group
Exploration and Production
Trade and Storage
Distribution
Generation
Q1 EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion
2,165
1,298
(71)
580
400
    Adjusted Q1 EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion
2,147
1,280
(71)
579
400
Q2 EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion
961
692
(160)
490
62
    Adjusted Q2 EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion
1,201
898
(160)
487
62
Q3 EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion
804
676
(221)
415
-19
    Adjusted Q3 EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion
756
630
(221)
413
-19
Q4 EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion
1,575
694
(16)
510
413
    Adjusted Q4 EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion
1,801
906
(14)
511
413

Quarterly EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion and adjusted EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion by operating segment in 2018 
2018
PLNm
PGNiG Group
Exploration and Production
Trade and Storage
Distribution
Generation
Q1 EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion
2,674
1,380
179
763
401
    Adjusted Q1 EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion
2,433
1,139
179
763
401
Q2 EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion
1,627
1,187
(209)
622
65
    Adjusted Q2 EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion
1,555
1,116
(209)
620
65
Q3 EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion
1,468
1,376
(469)
579
34
    Adjusted Q3 EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion
1,329
1,245
(469)
579
34
Q4 EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion
1,347
1,076
(349)
422
288
    Adjusted Q4 EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion
1,574
1315
(349)
424
272

Discussion of the PGNiG Group’s statement of financial position

As at December 31st 2019, total assets recognised in the consolidated statement of financial position were PLN 59,185m, up PLN 5,914m (10%) on the end of 2018.

Assets

Selected items of the statement of financial position – Assets [PLN m]

Property, plant and equipment represent the largest item of the PGNiG Group’s assets. As at December 31st 2019, property, plant and equipment amounted to PLN 40,002m, up PLN 5,766m (17%) relative to December 31st 2018. The balance of impairment losses on those assets rose by PLN 400m year on year. Equity-accounted investees fell by PLN 242m (or -13%) year on year, mainly following valuation of the investment in Polska Grupa Górnicza S.A.

As at the end of 2019, the PGNiG Group’s current assets were PLN 15,246m, having grown by PLN 873m (6%) on end of 2018, with a 23% (PLN 888m) year-on-year decrease in cash and cash equivalents. The growth in current assets was driven chiefly by a PLN 1,298m increase in financial derivatives, and a higher amount of inventories, which stood at PLN 4,042m as at the end of 2019, up PLN 678m (20%) relative to the end of 2018.

Equity and liabilities

Selected items of the statement of financial position – Equity and liabilities [PLN m]

 

Equity is the main source of financing of the PGNiG Group’s assets. At the end of 2019, the Group’s equity was PLN 38,107m, up PLN 1,475m (4%) relative to the end of 2018. The change was mainly attributable to the net profit earned in the reporting period – retained earnings grew by PLN 851m yoy, with hedging reserve up PLN 666m yoy.

As at the end of 2019, non-current liabilities stood at PLN 10,378m, up PLN 3,123m (43%) on December 31st 2018. The change in non-current liabilities was mainly attributable to lease liabilities – effect of the application of IFRS 16 of PLN 1,036m in 2019.

As at December 31st 2019, the PGNiG Group’s current liabilities amounted to PLN 10,700m, up PLN 1,316m (14%) relative to the end of 2018. The increase was mainly attributable to higher lease liabilities – effect of the application of IFRS 16 of PLN 793m in 2019, and bid bonds of PLN 463m paid in 2019.

For the full version of the consolidated statement of financial position, see The consolidated financial statements of the PGNiG Group for 2019.

Discussion of the statement of cash flows

PGNiG Group capital expenditure in 2019 by segment: Exploration and Production – PLN 2,446m; Trade and Storage – PLN 79m; Distribution – PLN 2,265m and Generation – PLN 1,074m

Dividends paid of PLN 636m (PLN 0.11 per share).

Lease liabilities, including non-current liabilities of PLN -1,043m and current liabilities of PLN -793m

For the full version of the consolidated statement of cash flows, see The consolidated financial statements of the PGNiG Group for 2019.

 

 

Selected items of the statement of cash flows [PLN m]

 

Profitability ratios

ROEre­turn on equ­ity, net pro­fit to equ­ity at end of pe­riod [%]

ROEre­turn on equ­ity, net pro­fit to equ­ity at end of pe­riod: net profit to equity at end of period

Lower ROEre­turn on equ­ity, net pro­fit to equ­ity at end of pe­riod, on a decrease in net profit (close to 60%) coupled with a 4% growth in equity in 2019 compared with 2018.

 ROAre­turn on as­sets, net pro­fit to as­sets at end of pe­riod [%]

ROAre­turn on as­sets, net pro­fit to as­sets at end of pe­riod: net profit to assets at end of period

Higher ROAre­turn on as­sets, net pro­fit to as­sets at end of pe­riod, on a decrease in net profit (close to 60%) coupled with an 11% growth in assets in 2019 compared with 2018.

Net margin [%]

Net margin: net profit to revenue

Lower net margin, on a decrease in net profit (close to 60%) coupled with a 2% growth in revenue compared with 2018.

Anticipated financial condition and trends on key product markets 

 
PGNiG Group’s anticipated financial condition

In the coming periods, the financial standing of the PGNiG Group will be materially affected by changes in the prices of hydrocarbons on global commodity markets and fluctuations in foreign exchange rates. These factors will be a material driver of the PGNiG Group’s performance in the Exploration and Production and Trade and Storage segments.

Any changes in hydrocarbon prices affect revenues of the Group entities engaged in production, and determine the demand for seismic and exploration services offered by the Group companies. Rising gas and crude oil prices have a positive effect on the performance of the Exploration and Production segment. Long-term forecasts of hydrocarbon prices strongly influence projected cash flows from production assets, and as a consequence entail the necessity of revaluation of property, plant and equipment.

On the other hand, since the prices of gas purchased by PGNiG under the Yamal and Qatar contracts are linked to prices of crude oil, the effect of rising oil prices on the performance of the Trade and Storage segment is opposite to the effect that rising oil prices have on the performance of the Exploration and Production segment. Any increase in crude oil prices translates into higher cost of gas purchased by PGNiG. This correlation may change following a ruling by the Stockholm Arbitration Tribunal regarding the price formula used in the Yamal contract.

The PGNiG Group’s financial results will also be influenced by the situation on the domestic currency market. Any strengthening of the złoty against foreign currencies (primarily the US dollar) will have a positive effect on the performance of the Trade and Storage segment by driving down PGNiG’s gas procurement costs, although it must be noted that the effect of exchange rate fluctuations is mitigated by the PGNiG Group’s hedging policy.

Another factor with a bearing on the PGNiG Group’s financial condition is the President of URE’s decisions on gas fuel sale and distribution tariffs and heat sale tariffs. In addition, the progressing deregulation of the gas market in Poland will continue to put pressure on the performance of the PGNiG Group’s Trade and Storage companies selling gas. In view of the competition for customers, the Group offers discount schemes to customers and adjusts pricing terms to reflect market prices. These factors may have an adverse effect on the profitability of the Trade and Storage segment by eroding its margins.

However, the PGNiG Group companies have put in place a number of initiatives to improve efficiency. These initiatives focus, among other things, on optimisation of the cost base and are expected to have a positive effect on the PGNiG Group’s financial results.

In the Generation segment, financial results will be considerably influenced by the support programmes for electricity produced from high-efficiency cogeneration sources and renewable sources. Changes in the market prices of CO2 emission allowances will have an increasing effect on the PGNiG Group’s financial condition in the segment. Another key driver of the segment’s performance is prices of the fuels used to produce heat and electricity.

Outlook for the oil, gas, electricity and CO2 emission allowances market

In early 2020, the United States Energy Information Administration (EIA) published its 2020 Brent crude price forecast, which puts the average month-ahead contract price for Brent at USD 64.83/bbl. Based on EIA’s projections, WTI will trade at USD 59.25/bbl. EIA has explained the absence of any major price changes by pointing to the balancing of the following factors: the effects of increased supply of crude oil from non-OPEC producers and the improving outlook for global economic growth following the signing of the trade agreement between the US and China. In addition, the OPEC group stabilises the market by limiting the supply depending on the market price levels. In 2019, it imposed stricter production limits when the Brent price fell below USD 60/bbl.

In a longer term, oil prices may be driven by political factors. At the end of 2019, for the first time in history the United States became net oil exporter. Iran and Venezuela have high spare capacities but their exports are limited by sanctions. Since the sanctions were introduced, the two countries’ production has fallen by 3m bbl/d in total. OPEC’s output is also lower than permitted by the technical capabilities of its member states. At the OPEC meeting in December the Saudi Arabia’s Minister of Energy announced that if other countries fail to meet their production quotas, Saudi Arabia would start exporting oil in maximum possible quantities. This would mean that an additional 3m bbl/d of oil would be placed on the market, producing a surplus that could lead to a situation similar to that seen in Q1 2016, when the price of Brent crude month-ahead contracts did not exceed USD 40/bbl.

The average price of Brent in 2020 could be USD 61/bbl. 2020 and the beginning of 2021 may be a period of lower prices, followed by a slow but consistent growth in the crude value for approximately 15 years, the reason being production from less and less profitable sources. The global demand for crude is expected to peak in the second half of the 2030s.

According to analysts, the price of natural gas in Europe will remain at the H2 2019 levels. Increased shale gas production in North America and Australia and launch of new units for liquefying natural gas will result in a continued rapid growth of the LNG output. In 2020, liquefaction capacities of approximately 364 TWh are planned to be put into service, of which 307 TWh will be located in the United States. An oversupply of LNG on the global market and higher volumes of Russian gas delivered to Germany will be offset by declining production in continental Europe (including from the Groningen field), periodic profitability of gas exports to Asia, and greater demand for gas in the power sector. The entry into force of the IMO 2020 regulations may also increase demand for LNG from maritime transport. Some LNG tankers use liquefied gas to power their engines, and that fuel complies with the environmental requirements provided for in the regulations. Liquefied gas may also be used as main fuel by conventional maritime transport. In view of the increasing environmental standards, further growth of this segment may be expected. Analysts estimate that in the current decade global consumption of LNG as fuel in maritime transport will rise at 23% annually, reaching 318 TWh in 2030. The strongest growth in demand for LNG will be seen in Asia, although it will be almost two times slower than in 2018–2019. Europe will continue to be a balancing market for global LNG supplies.

The price of CO2 emission allowances (EUAs) will largely depend on the final provisions of the agreement on the withdrawal of the United Kingdom from the European Union, the ratio of the natural gas price to coal price, and the pace of economic growth in Europe. In 2019, the EUA price growth was mitigated by the risk of UK’s exit from the European Union Emissions Trading System (EU ETS) during the term of contracts held by UK companies. This scenario would result in a large oversupply of EUAs in the continental part of Europe, driving a strong price decline. Currently, it is considered most likely that the UK will leave the EU ETS at the end of 2020, so the supply of contracts for 2021 would reflect the lower demand. In such a case, the price of CO2 emission allowances will depend on the coal price to gas price ratio. Generation of one unit of electricity from natural gas results in the release of carbon dioxide into the atmosphere in an amount that is on average more than two times smaller than in the case of coal-fired generation, so low gas prices may lead to reduced demand for EUAs, and thus to the price remaining at the levels seen in the second half of 2019 (approximately EUR 25).

Based on analysts’ forecasts, in 2020 electricity prices in Poland will not be higher than the average prices in 2019. The launch of new generation capacities at the power plants in Żerań and Stalowa Wola (gas-fired generation) and Jaworzno (coal-fired generation), connection of the Polish system to the European Single Intraday Coupling Market (SIDC/XBID), and development of the RES market are expected to prevent price growth. Increasing popularity of photovoltaic technologies may lead to a change in price seasonality patterns, as the largest amounts of energy from solar sources are generated in the second and third quarters of the year, when the prices generally reach their highs.

 

Publication of financial and operating forecasts

The Company does not publish performance forecasts.

In the strategy released in 2017, the Company announced its plans to generate cumulative Group EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion of approximately PLN 33.7bn in 2017–2022 thanks to an investment programme. As at the end of 2019, cumulative EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion reached PLN 19.2bn, representing 57% of the target to be achieved by 2022.

PGNiG Group’s cumulative EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion in 2017–2022 [PLNbn]

On July 31st 2019, PGNiG published its oil and gas production forecasts for 2019–2021.

Natural gas production forecast for 2019–2021*
bcm
2019
2019 – actual
2020
2021
Poland
3.9
3.8
3.9
4.0
Other countries, including:
0.7
0.7
0.9
1.2
 - Norway
0.5
0.5
0.5
0.7
 - Pakistan
0.2
0.2
0.4
0.5
Total
4.6
4.5
4.8
5.2
* Converted to gas with a calorific value of 39.5 MJ/m3. 

Production of natural gas in Poland, Norway and Pakistan remained stable owing to, among other things, the tie-in of new wells. 

The planned tying-in of the Ærfugl field in Norway will increase the output after 2020.

Crude oil production forecast, including condensate and NGL, for 2019–2021
thousand tonnes
2019
2019 – actual
2020
2021
Poland
778
776
747
733
Other countries, including:
475
440
611
671
 - Norway
475
440
611
671
Total
1,253
1,216
1,358
1,404

Crude oil production in Poland is gradually declining due to natural depletion. Similar developments are taking place in Norway, where production volumes were additionally affected by technical problems in the Vilje and Vale fields.

On the other hand, the planned launch of extraction from the Skogul and Ærfugl fields in 2020 and from the Duva field in 2021 will significantly increase the production volumes in 2020–2021.

Management of financial resources and liquidity of the PGNiG Group

Described in detail in "CREDITS, LOANS, BONDS"

Financial condition of PGNiG in 2019

PGNiG’s financial data for 2017–2019 [PLN m]
 PGNiG
2019
2018
2017
2019/2018 change
2019/2018 change (%)
Revenue
22,615
22,344
19,061
271
1%
Total operating expenses, including
(22,229)
(20,505)
(17,967)
(1,724)
8%
Operating profit before interest, taxes, depreciation and amortisation (EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion)
1,241
2,637
1,869
(1,396)
(53%)
Depreciation and amortisation expense
(856)
(798)
(766)
(58)
7%
Operating profit
386
1,839
1,094
(1,453)
(79%)
Profit before tax
1,989
3,677
2,290
(1,688)
(46%)
Net profit
1,748
3,289
2,034
(1,541)
(47%)
Net cash from operating activities
1,989
2,658
862
(669)
(25%)
Net cash from investing activities
(2,256)
644
(88)
(2,900)
(4.5)
Net cash from financing activities
(52)
(138)
(4,017)
86
(62%)
Net increase/(decrease) in cash and cash equivalents
(319)
3,164
(3,243)
(3,483)
(1.1)
           

 

Dec 31 2019
Dec 31 2018
Dec 31 2017
2019/2018 change
2019/2018 change (%)
Total assets
41,044
36,993
33,447
4,051
11%
Non-current assets
28,885
25,742
24,234
3,143
12%
Current assets, including
12,159
11,251
9,213
908
8%
Inventories
3,230
2,691
2,231
539
20%
Total equity and liabilities
41,044
36,993
33,447
4,051
11%
Total equity
30,618
28,833
26,033
1,785
6%
Total non-current liabilities
3,315
2,551
2,288
764
30%
Total current liabilities
7,111
5,609
5,126
1,502
27%
Total liabilities
10,426
8,160
7,414
2,266
28%

In 2019, PGNiG reported EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion of PLN 1,241m, down PLN 1,396m year on year. 

Change in PGNiG’s EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion: 2018 vs 2019 [PLN m]

 

The year-on-year decline in EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion (down PLN 1,288m) in the Exploration and Production segment was attributable to a lower result on sales of high-methane gas and crude oil, driven by lower prices on commodity exchanges (TTF, PPX, Brent), as well as smaller volumes of crude oil production and sales. The segment’s EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion was also affected by the change in impairment losses on property, plant and equipment and property, plant and equipment under construction forming part of exploration and evaluation assets.

EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion in the Trade and Storage segment fell PLN -107m year on year, driven by a lower result on sales of high-methane gas, due to lower commodity prices on exchange markets. The segment’s EBITDAear­nings be­fo­re in­te­rest, ta­xes, de­pre­cia­tion and amor­ti­za­tion was also affected by a change in gas inventory write-downs.

Financial ratio analysis

Profitability

 ROEre­turn on equ­ity, net pro­fit to equ­ity at end of pe­riod i ROAre­turn on as­sets, net pro­fit to as­sets at end of pe­riod [%]

ROEre­turn on equ­ity, net pro­fit to equ­ity at end of pe­riod: net profit to equity at end of period
ROAre­turn on as­sets, net pro­fit to as­sets at end of pe­riod: net profit to assets at end of period

The decrease in ROEre­turn on equ­ity, net pro­fit to equ­ity at end of pe­riod and ROAre­turn on as­sets, net pro­fit to as­sets at end of pe­riod in 2019 was due to year-on-year decline in net profit.

Net margin [%]

Net margin: net profit to revenue

The lower net margin in 2019 was caused by the year-on-year decrease in net profit and a PLN 680m rise in impairment losses

Debt ratios

Debt ratio and debt to equity ratio

Debt ratio: total liabilities to total equity and liabilities
Debt to equity ratio: total liabilities to equity

In 2019, the ratios increased, driven by higher liabilities, including in particular trade payables, and borrowings and debt securities

Liquidity ratios

Current ratio and quick ratio

Current ratio: current assets to current liabilities (net of employee benefit obligations, provisions and deferred income)

Quick ratio: current assets less inventories to current liabilities (net of employee benefit obligations, provisions and deferred income)
The decrease in the ratios in 2019 was attributable to higher current liabilities, mainly trade payables and borrowings and debt securities.

PGNiG’s capital expenditure in 2018–2019 [PLNm]
Capital expenditure* on property, plant and equipment made by PGNiG in 2019
 
 
Performance vs CAPEX plan
 
2019
2018
2017
2019
I.
Exploration and Production, including:
997
989
867
83%
1
Exploration
614
764
475
73%
 
including expenditure on dry wells
109
99
60
98%
2
Production
384
225
392
100%
II.
Trade and Storage
93
87
47
92%
1
Trade
62
0
3
100%
2
Storage facilities used by the Trade and Storage segment
31
87
43
78%
III.
Other segments
49
138
134
29%
IV.
Total capital expenditure (I+II+III)
1,140
1,213
1,047
76%
* Including capitalised borrowing costs.

 

 

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