Earnings Release • Jul 31, 2017
Earnings Release
Open in ViewerOpens in native device viewer
July 31, 2017
| 1. | 2Q17 HIGHLIGHTS 3 |
||
|---|---|---|---|
| 2. | KEY FIGURES4 | ||
| 3. | MARKET ENVIRONMENT5 | ||
| 4. | EXPLORATION & PRODUCTION6 | ||
| 5. | REFINING & MARKETING8 | ||
| 6. | GAS & POWER 10 |
||
| 7. | FINANCIAL DATA12 | ||
| 7.1. | Income statement 12 |
||
| 7.2. | Capital expenditure14 | ||
| 7.3. | Cash Flow 15 |
||
| 7.4. | Financial position and debt 17 |
||
| 7.5. | RCA turnover by segment18 | ||
| 7.6. | Reconciliation of IFRS and replacement cost adjusted figures 19 |
||
| 7.7. | IFRS consolidated income statement21 | ||
| 7.8. | Consolidated financial position 22 |
||
| 8. | BASIS OF PRESENTATION 23 |
||
| 9. | DEFINITIONS 24 |
Financial data €m (RCA)
| Quarter | First Half | ||||||||
|---|---|---|---|---|---|---|---|---|---|
| 2Q16 | 1Q17 | 2Q17 | Var. YoY | % Var. YoY |
2016 | 2017 | Var. YoY | % Var. YoY |
|
| 337 | 419 | 473 | 136 | 40% | Ebitda RCA | 631 | 892 | 262 | 41% |
| 86 | 204 | 188 | 101 | n.m. | Exploration & Production | 135 | 391 | 257 | n.m. |
| 143 | 187 | 233 | 90 | 63% | Refining & Marketing | 291 | 420 | 129 | 45% |
| 97 | 22 | 46 | (51) | (53%) | Gas & Power | 187 | 68 | (119) | (64%) |
| 185 | 220 | 253 | 68 | 37% | Ebit RCA | 323 | 473 | 151 | 47% |
| 131 | 286 | 199 | 68 | 52% | Ebit IFRS | 128 | 485 | 357 | n.m. |
| 133 | 99 | 151 | 18 | 14% | Net income RCA | 247 | 250 | 3 | 1% |
| (98) | (18) | (17) | 82 | 83% | Non-recurring items | (178) | (35) | 144 | 81% |
| 31 | 54 | (35) | (66) | n.m. | Inventory effect | (61) | 18 | 79 | n.m. |
| 66 | 134 | 99 | 34 | 51% | Net income IFRS | 8 | 234 | 226 | n.m. |
| 287 | 227 | 184 | (103) | (36%) | Capex | 630 | 411 | (219) | (35%) |
| (157) | (58) | 130 | - | - | Post-dividend free cash flow | (253) | 73 | - | - |
| 1,891 | 1,333 | 1,329 | (562) | (30%) | Net debt including loan to Sinopec1 | 1,891 | 1,329 | (562) | (30%) |
| 1.6x | 1.0x | 0.9x | - | - | Net debt to Ebitda RCA2 | 1.6x | 0.9x | - | - |
1Considering loan to Sinopec as cash. 2As at 30 June 2017, ratio considers net debt including €527 m loan to Sinopec as cash, plus €165 m of Sinopec MLT shareholder loan to Petrogal Brasil and LTM Ebitda RCA of €1,673 m.
| Quarter | First Half | ||||||||
|---|---|---|---|---|---|---|---|---|---|
| 2Q16 | 1Q17 | 2Q17 | Var. YoY | % Var. YoY |
2016 2017 |
Var. YoY | % Var. YoY |
||
| 54.7 | 88.0 | 89.9 | 35.1 | 64% | Average working interest production (kboepd) |
55.5 | 88.9 | 33.4 | 60% |
| 52.2 | 86.2 | 88.1 | 35.9 | 69% | Average net entitlement production (kboepd) | 53.0 | 87.2 | 34.2 | 65% |
| 38.3 | 45.4 | 43.4 | 5.1 | 13% | Oil and gas average sale price (USD/boe) | 32.1 | 43.9 | 11.8 | 37% |
| 26.3 | 26.1 | 30.0 | 3.7 | 14% | Raw materials processed (mmboe) | 51.5 | 56.1 | 4.6 | 9% |
| 4.6 | 5.1 | 5.7 | 1.2 | 26% | Galp refining margin (USD/boe) | 4.3 | 5.5 | 1.1 | 26% |
| 2.3 | 2.1 | 2.3 | 0.0 | 1% | Oil sales to direct clients (mton) | 4.4 | 4.4 | (0.0) | (1%) |
| 881 | 1,149 | 1,052 | 170 | 19% | NG sales to direct clients (mm3 ) |
1,782 | 2,201 | 419 | 23% |
| 712 | 857 | 675 | (37) | (5%) | NG/LNG trading sales (mm3 ) |
1,672 | 1,532 | (140) | (8%) |
| Quarter | First Half | |||||||||
|---|---|---|---|---|---|---|---|---|---|---|
| 2Q16 | 1Q17 | 2Q17 | Var. YoY | % Var. YoY |
2016 | 2017 | Var. YoY | % Var. YoY |
||
| 1.13 | 1.06 | 1.10 | (0.03) | (2%) | Average exchange rate (EUR:USD) | 1.12 | 1.08 | (0.03) | (3%) | |
| 45.6 | 53.7 | 49.6 | 4.1 | 9% | Dated Brent price1 (USD/bbl) |
39.8 | 51.7 | 11.9 | 30% | |
| (2.2) | (1.8) | (1.2) | (1.1) | (48%) | Heavy-light crude price spread1 (USD/bbl) |
(2.3) | (1.5) | (0.8) | (34%) | |
| 4.4 | 6.0 | 4.8 | 0.4 | 9% | U.K. NBP gas price1 (USD/mmbtu) |
4.3 | 5.4 | 1.1 | 25% | |
| 2.2 | 3.1 | 3.1 | 0.9 | 40% | U.S. Henry Hub gas price2 (USD/mmbtu) |
2.1 | 3.1 | 1.0 | 46% | |
| 4.7 | 7.0 | 5.5 | 0.9 | 18% | LNG Japan and Korea price1 (USD/mmbtu) |
4.8 | 6.3 | 1.5 | 30% | |
| 2.9 | 3.5 | 4.3 | 1.4 | 49% | Benchmark refining margin3 (USD/bbl) |
3.1 | 3.9 | 0.8 | 26% | |
| 15.4 | 15.2 | 15.7 | 0.3 | 2% | Iberian oil market4 (mton) | 30.5 | 30.9 | 0.4 | 1.3% | |
| 7,020 | 9,734 | 7,634 | 613 | 9% | Iberian natural gas market5 (mm3 ) |
15,674 | 17,367 | 1,694 | 10.8% |
1Source: Platts. Urals NWE dated for heavy crude; dated Brent for light crude. 2 Source: Nymex.
3For a complete description of the method of calculating the benchmark refining margin see "Definitions".
4Source: APETRO for Portugal; CORES for Spain. 5 Source: Galp and Enagás.
During the second quarter of 2017, the average price of dated Brent increased \$4.1/bbl YoY to \$49.6/bbl, following expectations of market rebalancing, particularly following OPEC's production restriction agreement, which was extended until March 2018.
During the first half of 2017, dated Brent averaged \$51.7/bbl, up \$11.9/bbl YoY.
During the second quarter of 2017, the average price spread between Urals and dated Brent decreased from -\$2.2/bbl, in the previous year, to -\$1.2/bbl. The relative valuation of Urals was due to the lower availability of this and other similar quality crudes produced by OPEC members, following the agreed production limits. During the first half of 2017, this average price spread narrowed \$0.8/bbl YoY to -\$1.5/bbl.
The natural gas price in Europe (NBP) increased from \$4.4/mmbtu the previous year to \$4.8/mmbtu during the second quarter of 2017, as a result of lower production in Western Europe, as well as the announcement of the closure of the largest natural gas storage facility in the United Kingdom.
During the first half of 2017, NBP averaged \$5.4/mmbtu, up \$1.1/mmbtu YoY.
The LNG reference price in the USA (Henry Hub) increased from \$2.2/mmbtu in the second quarter of 2016 to \$3.1/mmbtu. This increase was due to lower natural gas production and inventories in the USA, as well as the development of new LNG export projects.
During the first half of 2017, Henry Hub increased \$1.0/mmbtu YoY to \$3.1/mmbtu.
During the second quarter, the benchmark refining margin went up \$1.4/bbl YoY to \$4.3/bbl, as a result of stronger diesel and fuel oil cracks. During the first half, the benchmark margin increased \$0.8/bbl YoY to \$3.9/bbl.
The diesel crack increased \$1.0/bbl YoY to \$11.9/bbl in the quarter, due to increased demand and unplanned outages in refineries in Central Europe. During the first half of 2017, the diesel crack was \$11.8/bbl, up \$1.8/bbl YoY.
The fuel oil crack was -\$3.5/bbl, an improvement of \$9.2/bbl YoY, following lower inventories, which stemmed primarily from: lower exports from Russia, as a result of its upgrade programme and the higher taxes on fuel exports; and the reduction in the average residue yield of the crude oil available on the market, following the OPEC agreement.
During the first half of 2017, the fuel crack averaged -\$4.4/bbl, compared to -\$12.3/bbl during the first half of 2016.
During the second quarter of 2017, the Iberian market for oil products totalled 15.7 million tonnes (mton), compared to 15.4 mton the previous year, as demand for jet increased, driven by a pick-up in tourism activity.
During the first half of 2017, the Iberian market for oil products rose 1% YoY to 30.9 mton.
During the second quarter of 2017, the Iberian natural gas market increased 9% YoY to 7,634 mm³, supported by a 52% increase in the electrical segment consumption, during a period of lower hydroelectric power generation.
During the first half, the Iberian natural gas market increased 11% YoY to 17,367 mm³.
€m (RCA, except otherwise stated; unit figures based on net entitlement production)
| Quarter | First Half | ||||||||
|---|---|---|---|---|---|---|---|---|---|
| 2Q16 | 1Q17 | 2Q17 | Var. YoY | % Var. YoY |
2016 | 2017 | Var. YoY | % Var. YoY |
|
| 54.7 | 88.0 | 89.9 | 35.1 | 64% | Average working interest production1 55.5 (kboepd) |
88.9 | 33.4 | 60% | |
| 51.7 | 76.9 | 78.0 | 26.3 | 51% | Oil production (kbpd) | 52.3 | 77.4 | 25.2 | 48% |
| 52.2 | 86.2 | 88.1 | 35.9 | 69% | Average net entitlement production1 (kboepd) |
53.0 | 87.2 | 34.2 | 65% |
| 7.1 | 6.9 | 6.2 | (0.9) | (13%) | Angola | 7.5 | 6.6 | (1.0) | (13%) |
| 45.0 | 79.3 | 81.8 | 36.8 | 82% | Brazil | 45.4 | 80.6 | 35.2 | 77% |
| 38.3 | 45.4 | 43.4 | 5.1 | 13% | Oil and gas average sale price (USD/boe) |
32.1 | 43.9 | 11.8 | 37% |
| 3.8 | 4.6 | 4.3 | 0.5 | 13% | Royalties2 (USD/boe) |
3.3 | 4.4 | 1.1 | 33% |
| 9.8 | 8.0 | 9.2 | (0.6) | (6%) | Production costs (USD/boe) | 9.3 | 8.6 | (0.8) | (8%) |
| 14.8 | 13.4 | 14.2 | (0.7) | (5%) | Depreciation & Amortisation3 (USD/boe) |
15.4 | 13.8 | (1.6) | (10%) |
| 86 | 204 | 188 | 101 | n.m. | Ebitda RCA | 135 | 391 | 257 | n.m. |
| 63 | 97 | 103 | 40 | 64% | Depreciation, Amortisation and Impairments3 | 133 | 200 | 67 | 51% |
| - | - | 22 | 22 | n.m. | Exploration expenditures written-off4 | - | 22 | 22 | n.m. |
| (0) | - | - | 0 | n.m. | Provisions | (0) | - | 0 | n.m. |
| 24 | 106 | 63 | 39 | n.m. | Ebit RCA | 2 | 169 | 167 | n.m. |
| (62) | 108 | 59 | 121 | n.m. | Ebit IFRS | (93) | 168 | 261 | n.m. |
| 8 | 9 | 8 | 0 | 2% | Net Income from E&P Associates | 11 | 16 | 6 | 54% |
1 Includes natural gas exported; excludes natural gas used or reinjected.
2 Based on production in Brazil.
3 Includes abandonment provisions and excludes exploration expenditures written-off.
4Effective from 1 January 2017, exploration expenses written-off are considered as recurring items.
During the second quarter of 2017, working interest production of oil and natural gas averaged 89.9 kboepd, of which 87% was oil.
Production increased 64% YoY, supported by the development of the Lula/Iracema projects in Brazil, and particularly to the start-up of FPSO #6 and #7 and to the ramp-up of FPSOs #4 and #5.
On May 17, FPSO #7, the first replicant unit allocated to the Brazilian pre-salt, started production in the Lula South area. In Lula Central, FPSO Cidade de Saquarema (FPSO #6) reached plateau production in June, 11 months after coming onstream.
The planned maintenance works in some units in Brazil impacted production during the period, in particular the outage at FPSO #3 in Iracema South and the maintenance works at FPSO #1 in the Lula Pilot area.
Regarding the replicant unit to be allocated to the Lula North area (FPSO #8), the topsides' integration works proceed at COOEC's shipyard, in China. As for the hull of the replicant to develop the Lula Extreme South area (FPSO #9), it arrived during the quarter at the Brasfels shipyard and the integration works are underway.
In Angola, working interest production from BBLT and TL amounted to 8.0 kbpd, down 17% YoY as
production from fields in block 14 continues to decline. Net entitlement production decreased 13% YoY, helped by the cost-recovery mechanism established under the production-sharing contracts.
Galp's net entitlement production increased 69% YoY to 88.1 kboepd, following production growth in Brazil.
During the first half of 2017, working interest production was 88.9 kboepd, a 60% increase YoY, which was due to the increase in production from Brazil, where seven units are already in production, compared to five units in the previous year.
Net entitlement production went up 65% YoY to 87.2 kboepd.
Ebitda RCA amounted to €188 m, up €101 m YoY, mainly on the back of increased production and higher sale prices of oil and natural gas. The average sale price was \$43.4/boe, compared to \$38.3/boe in the second quarter of 2016.
Production costs increased €25 m YoY to €67 m, mainly due to the contribution of FPSOs #6 and #7, which started production in July 2016 and May 2017, respectively. In unit terms, and on a net entitlement basis, production costs decreased by \$0.6/boe YoY to \$9.2/boe, benefiting from a higher production dilution effect.
During the second quarter, amortisation and depreciation charges (including abandonment provisions) amounted to €103 m, up €41 m YoY, on the back of increased producing assets in Brazil. On a net entitlement basis, depreciation charges decreased from \$14.8/boe to \$14.2/boe.
In the quarter, a €22 m impairment was made regarding the relinquishment of exploration blocks in Portugal. It should be noted that, as of 1 January 2017, exploration expenses written-off started to be accounted for as recurring items.
RCA Ebit totalled €63 m, up €39 m YoY. IFRS Ebit stood at €59 m.
During the first half of 2017, RCA Ebitda amounted to €391 m, up €257 m YoY, benefiting from higher production and average sale price, which reached \$43.9/boe, compared to \$32.1/boe in the second quarter of 2016.
Production costs increased €44 m YoY to €125 m, due to the higher number of operating units in Brazil. In unit terms, and on a net entitlement basis, production costs decreased from \$9.3/boe the previous year to \$8.6/boe.
Amortisation, depreciation charges and abandonment provisions amounted to €200 m, up €68 m YoY following higher production. On a net entitlement basis, unit depreciation charges were \$13.8/boe, against \$15.4/boe in the previous year.
RCA Ebit went up to €169 m, although impacted by the exploration impairment in Portugal.
5. Refining & Marketing
€m (RCA, except otherwise stated)
| Quarter | First Half | |||||||||
|---|---|---|---|---|---|---|---|---|---|---|
| 2Q16 | 1Q17 | 2Q17 | Var. YoY | % Var. YoY |
2016 | 2017 | Var. YoY | % Var. YoY |
||
| 4.6 | 5.1 | 5.7 | 1.2 | 26% | Galp refining margin (USD/boe) | 4.3 | 5.5 | 1.1 | 26% | |
| 1.7 | 1.7 | 1.6 | (0.1) | (7%) | Refining cash cost1 (USD/boe) |
1.8 | 1.7 | (0.2) | (10%) | |
| (0.0) | (0.0) | (0.2) | (0.2) | n.m. | Impact of hedging on refining margin2 (USD/boe) |
0.1 | (0.1) | (0.2) | n.m. | |
| 26.3 | 26.1 | 30.0 | 3.7 | 14% | Raw materials processed (mmboe) | 51.5 | 56.1 | 4.6 | 9% | |
| 23.2 | 22.9 | 26.7 | 3.5 | 15% | Crude processed (mmbbl) | 47.1 | 49.6 | 2.5 | 5% | |
| 4.5 | 4.4 | 4.7 | 0.3 | 6% | Total refined product sales (mton) | 8.5 | 9.1 | 0.5 | 6% | |
| 2.3 | 2.1 | 2.3 | 0.0 | 1% | Sales to direct clients (mton) | 4.4 | 4.4 | (0.0) | (1%) | |
| 143 | 187 | 233 | 90 | 63% | Ebitda RCA | 291 | 420 | 129 | 45% | |
| 65 | 91 | 89 | 24 | 37% | Depreciation, Amortisation and Impairments | 130 | 179 | 50 | 38% | |
| 7 | 3 | (1) | (8) | n.m. | Provisions | 12 | 2 | (11) | (85%) | |
| 71 | 94 | 145 | 74 | n.m. | Ebit RCA | 149 | 239 | 90 | 61% | |
| 103 | 150 | 96 | (7) | (7%) | Ebit IFRS | 56 | 245 | 190 | n.m. | |
| (0) | (2) | 8 | 8 | n.m. | Net Income from R&M Associates | 0 | 6 | 6 | n.m. |
1Excluding impact of refining margin hedging operations.
2Impact on Ebitda.
Raw materials processed during the quarter increased 14% YoY to 30.0 mmboe, with the previous year impacted by lower benchmark refining margins and outages at the Matosinhos refinery. Crude oil accounted for 89% of raw materials processed, of which 83% corresponded to medium and heavy crudes.
During the period, 46% of oil products produced were middle distillates (diesel and jet) and 22% corresponded to gasoline. Consumption and losses accounted for 8% of raw materials processed.
Volumes sold to direct clients stood at 2.3 mton, in line with the second quarter of 2016. Volumes sold in Africa rose 22% YoY, accounting for c.10% of total volumes sold to direct clients.
Raw materials processed during the first half of 2017 increased 9% YoY to 56.1 mmboe, mainly as a result of the planned outage of the hydrocracker at the Sines refinery and in several units in Matosinhos during the previous year. Crude oil accounted for 88% of raw materials processed, of which 83% corresponded to medium and heavy crudes.
Middle distillates accounted for 47% of total production, while gasoline accounted for 23%. Consumption and losses stood at 8%.
Volumes sold to direct clients stood in line YoY at 4.4 mton, despite the decreased exposure to lower margin activities in Iberia, namely in the wholesale segment. Volumes sold in Africa increased 18% and accounted for 10% of total volumes sold to direct clients.
Results second quarter 2017 July 31, 2017
RCA Ebitda of R&M increased €90 m to €233 m, due to both the performance of the refining and oil products marketing activities.
Galp's refining margin stood at \$5.7/boe, compared to \$4.6/boe the previous year. The spread over the benchmark margin was \$1.4/boe, as the Company benefited from the high availability of the conversion units and sourcing opportunities.
Refining cash costs stood at €44 m, or \$1.6/boe.
The oil products marketing activity was supported by the economic environment in Iberia, which boosted demand, namely in the jet and marine bunkers segments. Activities in Africa increased their contribution to results.
Depreciation charges and provisions increased €16 m YoY to €88 m, following the revision of the useful life of certain refining assets made at the end of 2016.
RCA Ebit went up to €145 m, while IFRS Ebit totalled €96 m. The inventory effect was a negative €48 m.
Ebitda RCA increased €129 m to €420 m, supported by the market environment and the operational availability of the refineries.
Galp's refining margin stood at \$5.5/boe, compared to \$4.3/boe the previous year. The spread to benchmark margin was \$1.6/boe, as the Company benefited mainly from sourcing opportunities.
Refining cash costs stood at €86 m, in line YoY. In unit terms, cash costs were \$1.7/boe.
The marketing of oil products benefited from the higher demand in the retail segment and in the wholesale segment, related to the increased economic activity.
Depreciation charges and provisions totalled €181 m, up €39 m YoY.
RCA Ebit was €239 m, while IFRS Ebit increased to €245 m. The inventory effect was positive by €12 m.
6. Gas & Power
€m (RCA except otherwise stated)
| Quarter | First Half | ||||||||
|---|---|---|---|---|---|---|---|---|---|
| 2Q16 | 1Q17 | 2Q17 | Var. YoY | % Var. YoY |
2016 | 2017 | Var. YoY | % Var. YoY |
|
| 1,593 | 2,006 | 1,726 | 133 | 8% | NG/LNG total sales volumes (mm3 ) |
3,454 | 3,733 | 279 | 8% |
| 881 | 1,149 | 1,052 | 170 | 19% | Sales to direct clients (mm3 ) |
1,782 | 2,201 | 419 | 23% |
| 712 | 857 | 675 | (37) | (5%) | Trading (mm3 ) |
1,672 | 1,532 | (140) | (8%) |
| 1,229 | 1,350 | 1,170 | (59) | (5%) | Sales of electricity (GWh) | 2,421 | 2,520 | 99 | 4% |
| 380 | 496 | 348 | (32) | (8%) | Sales of electricity to the grid (GWh) | 735 | 844 | 108 | 15% |
| 97 | 22 | 46 | (51) | (53%) | Ebitda RCA | 187 | 68 | (119) | (64%) |
| 61 | 13 | 39 | (22) | (36%) | Natural Gas | 121 | 51 | (70) | (58%) |
| 33 | - | - | (33) | n.m. | Infrastructure1 | 65 | - | (65) | n.m. |
| 4 | 9 | 7 | 4 | n.m. | Power | 1 | 17 | 16 | n.m. |
| 15 | 5 | 5 | (10) | (69%) | Depreciation, Amortisation and Impairments | 30 | 9 | (20) | (69%) |
| 1 | 3 | 2 | 0 | 21% | Provisions | 1 | 4 | 3 | n.m. |
| 81 | 15 | 40 | (41) | (51%) | Ebit RCA | 156 | 55 | (101) | (65%) |
| 82 | 22 | 39 | (43) | (52%) | Ebit IFRS | 151 | 62 | (89) | (59%) |
| 17 | 25 | 25 | 8 | 50% | Net Income from G&P Associates1 | 34 | 50 | 16 | 47% |
1The regulated infrastructure business ceased to be fully consolidated as of the end of October 2016.
Volumes of natural gas sold amounted to 1,726 mm³, up 8% YoY driven by increased sales to direct clients.
Sales to direct clients increased 19%, mainly due to higher demand from the electrical segment, which had lower renewable power generation in Iberia.
Volumes sold in the conventional segment went up 7% YoY, mostly due to the performance in the industrial segment.
During the quarter, trading volumes decreased 5% to 675 mm3 , following lower LNG volumes sold under structured contracts.
Sales of natural gas were 3,733 mm³, up 279 mm³ compared to the first half of 2016, which reflected an increase in volumes sold to direct clients, mainly in the electrical segment.
Volumes sold in the conventional segment also increased 11%, following the performance of the industrial segment.
Volumes sold in the trading segment decreased 8% to 1,532 mm³, due to lower LNG volumes sold.
Sales of electricity were 2,520 GWh, a 99 GWh increase compared to the previous year, which had been impacted by an outage of the cogeneration in the Matosinhos refinery.
Results second quarter 2017 July 31, 2017
RCA Ebitda for the G&P business was down €51 m YoY to €46 m, following the deconsolidation of the regulated infrastructure business and the lower contribution from trading and the gas marketing activity in Iberia. Ebitda for the natural gas segment decreased €22 m YoY to €39 m.
Ebitda for the power business rose €4 m YoY to €7 m, benefiting from the time lag of the natural gas purchase price and the sale price of energy produced.
RCA Ebit decreased €41 m to €40 m, while IFRS Ebit was down to €39 m.
Results from associated companies reached €25 m, up €8 m YoY, reflecting the contribution in this caption of the 77.5% stake in Galp Gás Natural Distribuição S.A (GGND).
Ebitda was €68 m during the first half of 2017, down €119 m YoY, mainly following lower results from the natural gas activity and the deconsolidation of GGND.
Ebitda for the natural gas segment decreased €70 m YoY to €51 m, due to the lower contribution of LNG trading and the gas marketing activity in Iberia, and considering the negative sourcing impact during the first quarter of 2017.
Ebitda for the power business was €17 m, compared to €1 m in the first half of 2016, which had been impacted by the outage of the cogeneration unit in the Matosinhos refinery and by the negative lag of the natural gas purchase price and the sale price of energy produced.
RCA Ebit decreased €101 m YoY to €55 m. IFRS Ebit was €62 m, compared to €151 m the previous year.
Results from associated companies related to the G&P business reached €50 m, up €16 m YoY.
€m (RCA, except otherwise stated)
| Quarter | First Half | ||||||||
|---|---|---|---|---|---|---|---|---|---|
| 2Q16 | 1Q17 | 2Q17 | Var. YoY | % Var. YoY |
2016 | 2017 | Var. YoY | % Var. YoY |
|
| 3,267 | 3,844 | 3,779 | 512 | 16% | Turnover | 6,081 | 7,623 | 1,542 | 25% |
| (2,554) | (2,975) | (2,865) | 310 | 12% | Cost of goods sold | (4,710) | (5,840) | 1,131 | 24% |
| (310) | (376) | (383) | 73 | 24% | Supply & Services | (608) | (759) | 151 | 25% |
| (73) | (79) | (70) | (3) | (4%) | Personnel costs | (148) | (150) | 2 | 1% |
| 8 | 6 | 13 | 5 | 58% | Other operating revenues (expenses) | 16 | 18 | 2 | 13% |
| 337 | 419 | 473 | 136 | 40% | Ebitda RCA | 631 | 892 | 262 | 41% |
| 366 | 485 | 422 | 56 | 15% | Ebitda IFRS | 530 | 908 | 378 | 71% |
| (144) | (194) | (219) | 75 | 53% | Depreciation, Amortisation and Impairments | (295) | (413) | 118 | 40% |
| (8) | (5) | (1) | (8) | (89%) | Provisions | (13) | (6) | (7) | (54%) |
| 185 | 220 | 253 | 68 | 37% | Ebit RCA | 323 | 473 | 151 | 47% |
| 131 | 286 | 199 | 68 | 52% | Ebit IFRS | 128 | 485 | 357 | n.m. |
| 24 | 32 | 41 | 17 | 69% | Net income from associated companies | 45 | 73 | 27 | 61% |
| 15 | (12) | (10) | (25) | n.m. | Financial results | 18 | (22) | (40) | n.m. |
| (28) | (21) | (19) | (9) | (32%) | Net interests | (55) | (40) | (15) | (28%) |
| 25 | 24 | 27 | 2 | 10% | Interest capitalised | 46 | 51 | 5 | 11% |
| (0) | (3) | (10) | (10) | n.m. | Exchange gain (loss) | (7) | (13) | (7) | (96%) |
| 23 | (4) | (4) | (26) | n.m. | Mark-to-market of hedging derivatives | 44 | (7) | (52) | n.m. |
| (4) | (7) | (4) | (0) | 13% | Other financial costs/income | (9) | (12) | (3) | (27%) |
| 224 | 241 | 283 | 59 | 26% | Net income RCA before taxes and non controlling interests |
386 | 524 | 138 | 36% |
| (79) | (123) | (120) | 41 | 52% | Taxes¹ | (118) | (243) | 125 | n.m. |
| (12) | (18) | (12) | 0 | 1% | Non-controlling interests | (21) | (31) | 10 | 47% |
| 133 | 99 | 151 | 18 | 14% | Net income RCA | 247 | 250 | 3 | 1% |
| (98) | (18) | (17) | 82 | 83% | Non recurring items | (178) | (35) | 144 | 81% |
| 35 | 81 | 135 | 100 | n.m. | Net income RC | 69 | 215 | 147 | n.m. |
| 31 | 54 | (35) | (66) | n.m. | Inventory effect | (61) | 18 | 79 | n.m. |
| 66 | 134 | 99 | 34 | 51% | Net income IFRS | 8 | 234 | 226 | n.m. |
1Includes corporate income taxes and taxes payable on oil and gas production.
RCA Ebitda increased 40% YoY to €473 m, following a higher contribution from E&P and R&M. IFRS Ebitda rose €56 m to €422 m.
Considering the increase in depreciation and exploration impairments, RCA Ebit stood at €253 m. IFRS Ebit rose €68 m to €199 m.
Results from associated companies increased to €41 m, following the deconsolidation of the regulated infrastructure business.
Financial results were negative €10 m, down €25 m YoY, mainly due to a €26 m change in the mark-to-market of hedging derivatives, mainly related to refining margin hedging.
RCA taxes increased to €120 m, following the increase in the Group's operating results. Taxes on oil and gas production stood at €61 m, compared to €25 m in the previous year.
RCA net income reached €151 m, while IFRS net income was €99 m. The inventory effect was Results second quarter 2017 July 31, 2017
negative by €35 m and non-recurring items amounted to €17 m.
RCA Ebitda was €892 m during the first half of 2017, a 41% increase YoY, due to the enhanced performance of E&P and R&M. IFRS Ebitda rose €378 m to €908 m.
Considering the increase in depreciation, namely in E&P and R&M, RCA Ebit was up to €473 m. IFRS Ebit was up to €485 m.
Results from associated companies increased to €73 m.
Financial results were negative €22 m, down €40 m YoY, mainly due to a €52 m change in mark-to-market of hedging derivatives, namely related to refining margin hedging.
RCA taxes reached €243 m, mainly due to higher results in the E&P business, with taxes on oil and gas production reaching €130 m.
Non-controlling interests, mainly attributable to Sinopec's stake in Petrogal Brasil, reached €31 m.
RCA net income reached €250 m, while IFRS net income was €234 m. The inventory effect was €18 m and non-recurring items stood at €35 m.
CESE tax in Portugal had a negative impact on IFRS results of around €33 m, including €16 m related to CESE I, whose annual impact is fully accounted for in the first quarter of the year. This provision related to CESE results from the strict applicability of accounting standards. However, in Galp's opinion, based on the opinion of renowned national legal experts, the laws regarding CESE have no legal grounds and, accordingly, such amounts are not due.
| €m | |
|---|---|
| Quarter | First Half | ||||||||
|---|---|---|---|---|---|---|---|---|---|
| 2Q16 | 1Q17 | 2Q17 | Var. YoY | % Var. YoY |
2016 | 2017 | Var. YoY | % Var. YoY |
|
| 245 | 209 | 157 | (88) | (36%) | Exploration & Production | 561 | 366 | (195) | (35%) |
| 12 | 17 | 9 | (3) | (24%) | Exploration and appraisal activities | 21 | 26 | 4 | 20% |
| 233 | 192 | 148 | (85) | (36%) | Development and production activities | 540 | 340 | (200) | (37%) |
| 35 | 16 | 24 | (11) | (32%) | Refining & Marketing | 59 | 40 | (19) | (32%) |
| 7 | 2 | 2 | (4) | (62%) | Gas & Power | 9 | 4 | (5) | (56%) |
| 0 | 0 | 1 | 0 | n.m. | Others | 1 | 1 | 0 | 17% |
| 287 | 227 | 184 | (103) | (36%) | Capex | 630 | 411 | (219) | (35%) |
Capital expenditure during the quarter amounted to €184 m, down €103 m YoY, mainly due to the lesser intensity of drilling activities in Brazil.
Of the total investment, 85% was allocated to development and production activities in E&P, namely to the development of block BM-S-11 in Brazil and block 32 in Angola. Within the exploration and appraisal activities, it is worth highlighting the 3D seismic data campaign ongoing in São Tomé and Príncipe.
Investment in downstream activities (R&M and G&P) amounted to €26 m, and was allocated to refining maintenance and energy efficiency, as well as to the renovation of downstream retail assets.
Capital expenditure during the first half of 2017 amounted to €411 m, down 35% YoY, mainly due to the progress in the execution of Lula/Iracema.
E&P activities accounted for 89% of the total, with development activities in the BM-S-11 block accounting for 72% of the investment in E&P.
The €44 m investment in downstream activities was mainly aimed at refining maintenance activities, expansion of the downstream network and customer relationship management (CRM) programmes.
| €m (IFRS figures) | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|
| Quarter | First Half | ||||||||||
| 2Q16 | 1Q17 | 2Q17 | 2016 | 2017 | |||||||
| 131 | 286 | 199 | Ebit | 128 | 485 | ||||||
| 25 | - | 86 | Dividends from associates | 25 | 86 | ||||||
| 221 | 194 | 221 | Depreciation, Depletion and Amortisation (DD&A) | 383 | 415 | ||||||
| (8) | (230) | 159 | Change in Working Capital | 133 | (71) | ||||||
| 369 | 250 | 665 | Cash flow from operations | 669 | 915 | ||||||
| (269) | (205) | (185) | Net capex1 | (612) | (390) | ||||||
| (28) | (21) | (19) | Net financial expenses | (55) | (40) | ||||||
| (55) | (81) | (116) | Corporate income taxes and oil and gas production taxes | (80) | (197) | ||||||
| (175) | - | (215) | Dividends paid | (175) | (215) | ||||||
| (157) | (58) | 130 | Post-dividend free cash flow | (253) | 73 | ||||||
| 141 | 33 | (92) | Others2 | 191 | (59) | ||||||
| 16 | 24 | (39) | Change in net debt | 61 | (14) |
1The first quarter of 2017 includes the proceeds of €22 m from the sale of the 25% indirect stake in Âncora project. 2
Includes CTAs (Cumulative Translation Adjustment) and partial reimbursement of the loan granted to Sinopec.
Post-dividend free cash flow reached €130 m in the second quarter of 2017. This resulted from the robust operating results and the lower investment in the period, and despite the €215 m dividend payment in May 2017.
Cash flow from operations benefited not only from improved E&P and R&M performance, but also from the normalisation of inventories during the quarter.
At the end of June, post-dividend free cash flow totalled €73 m, on the back of the operating performance achieved on the second quarter.
| €m | |||||
|---|---|---|---|---|---|
| Quarter | First Half | ||||
| 2Q16 | 1Q17 | 2Q17 | 2016 | 2017 | |
| 954 | 923 | 858 | Cash and equivalents at the beginning of the period1 | 1,045 | 923 |
| 3,762 | 4,363 | 4,348 | Received from customers | 7,027 | 8,711 |
| (2,226) | (3,013) | (2,543) | Paid to suppliers | (4,062) | (5,556) |
| (106) | (71) | (98) | Staff related costs | (182) | (169) |
| 25 | - | 86 | Dividends from associated companies | 25 | 86 |
| (649) | (612) | (739) | Taxes on oil products (ISP) | (1,253) | (1,352) |
| (410) | (376) | (433) | VAT, Royalties, PIS, Cofins, Others | (790) | (808) |
| 395 | 290 | 620 | Total operating flows | 764 | 912 |
| (273) | (238) | (150) | Net capex2 | (652) | (367) |
| (32) | (50) | (23) | Net Financial Expenses | (84) | (73) |
| (175) | - | (215) | Dividends paid | (175) | (215) |
| (55) | (81) | (116) | SPT and Corporate taxes | (80) | (197) |
| (86) | (19) | 8 | Net new loans | (130) | (32) |
| 66 | 42 | - | Sinopec loan reimbursement | 134 | 42 |
| 60 | (11) | (79) | FX changes on cash and equivalents | 32 | (91) |
| 856 | 858 | 902 | Cash and equivalents at the end of the period1 | 856 | 902 |
1 Cash and equivalents differ from the Balance Sheet amounts due to IAS 7 classification rules. The difference refers to overdrafts which are considered as debt in the Balance Sheet and as a deduction to cash in the Cash Flow Statement.
2 The first quarter of 2017 includes the proceeds of €22 m from the sale of the 25% indirect stake in Âncora project.
€m (IFRS figures)
| 31 Dec., 2016 |
31 Mar., 2017 |
30 Jun., 2017 |
Var. vs 31 Dec., 2016 |
Var. vs 31 Mar., 2017 |
|
|---|---|---|---|---|---|
| Net fixed assets | 7,721 | 7,901 | 7,458 | (263) | (442) |
| Working capital | 512 | 742 | 583 | 71 | (159) |
| Loan to Sinopec | 610 | 561 | 527 | (83) | (34) |
| Other assets (liabilities) | (428) | (635) | (595) | (167) | 40 |
| Non-current assets/liabilities held for sale | (1) | - | - | 1 | - |
| Capital employed | 8,414 | 8,569 | 7,974 | (440) | (595) |
| Short term debt | 325 | 672 | 808 | 483 | 136 |
| Medium-Long term debt | 2,578 | 2,181 | 2,068 | (510) | (114) |
| Total debt | 2,903 | 2,853 | 2,876 | (27) | 22 |
| Cash and equivalents | 1,032 | 959 | 1,020 | (13) | 61 |
| Net debt | 1,870 | 1,895 | 1,856 | (14) | (39) |
| Total equity | 6,543 | 6,674 | 6,118 | (426) | (557) |
| Total equity and net debt | 8,414 | 8,569 | 7,974 | (440) | (595) |
On June 30, 2017, net fixed assets stood at €7,458 m, down €442 m compared to the end of March as both the US Dollar and the Brazilian Real depreciated against the Euro during the second quarter.
Work-in-progress, mainly related to the E&P business, was €2,460 m at the end of the period.
€m (except otherwise stated)
| 31 Dec., 2016 |
31 Mar., 2017 |
30 Jun., 2017 |
Var. vs 31 Dec., 2016 |
Var. vs 31 Mar., 2017 |
|
|---|---|---|---|---|---|
| Bonds | 1,683 | 1,684 | 1,663 | 19 | (21) |
| Bank loans and other debt | 1,220 | 1,169 | 1,212 | 8 | 43 |
| Cash and equivalents | (1,032) | (959) | (1,020) | (13) | (61) |
| Net debt | 1,870 | 1,895 | 1,856 | 14 | (39) |
| Net debt including loan to Sinopec1 | 1,260 | 1,333 | 1,329 | (68) | (5) |
| Average life (years) | 2.6 | 2.4 | 2.3 | 0.3 | (0.1) |
| Average debt interest rate | 3.5% | 3.5% | 3.5% | 0.0 p.p. | (0.0 p.p.) |
| Net debt to Ebitda RCA2 | 1.0x | 1.0x | 0.9x | - | - |
1Net debt of €1,329 m adjusted for the €527 m loan to Sinopec. 2As at 30 June 2017, ratio considers net debt including loan to Sinopec as cash, plus €165 m corresponding Sinopec MLT Shareholder Loan to Petrogal Brasil, and LTM RCA Ebitda of €1,673 m
On June 30, 2017, net debt stood at €1,856 m, down €39 m compared to the end of the first quarter.
Considering the €527 m balance of the Sinopec loan as cash, net debt at the end of the period totalled €1,329 m, resulting in a net debt to Ebitda ratio of 0.9x. This ratio also considers Sinopec's €165 m shareholder loan to Petrogal Brasil as of the end of the period.
The average interest rate was 3.48% during the period.
At the end of June, around 49% of total debt was on a fixed-rate basis. Debt had an average
maturity of 2.28 years, and medium and long-term debt accounted for 72% of total debt.
amount, around 70% was contractually guaranteed.
At the end of the first half, Galp had unused credit lines of approximately €1.3 bn. Of this
€m
| Quarter | First Half | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 2Q16 | 1Q17 | 2Q17 | Var. YoY | % Var. YoY |
2016 | 2017 | Var. YoY | % Var. YoY |
||||
| 3,267 | 3,844 | 3,779 | 512 | 16% | RCA Turnover | 6,081 | 7,623 | 1,542 | 25% | |||
| 165 | 308 | 307 | 142 | 86% | Exploration & Production1 | 276 | 615 | 339 | n.m. | |||
| 2,657 | 2,869 | 2,899 | 242 | 9% | Refining & Marketing | 4,809 | 5,768 | 959 | 20% | |||
| 545 | 713 | 614 | 69 | 13% | Gas & Power | 1,221 | 1,327 | 106 | 9% | |||
| 31 | 30 | 33 | 2 | 5% | Other | 59 | 62 | 3 | 5% | |||
| (131) | (75) | (74) | 57 | 43% | Consolidation adjustments | (284) | (149) | 135 | 47% | |||
1Does not include change in production. RCA turnover in the E&P segment, including change in production, amounted to €322 m during the second quarter and €653 m during the first half of 2017.
| Second Quarter | 2017 | First Half | ||||||||
|---|---|---|---|---|---|---|---|---|---|---|
| Ebitda IFRS |
Inventory Ebitda effect RC |
Non recurring items |
Ebitda RCA |
Ebitda IFRS |
Inventory effect |
Ebitda RC |
Non recurring items |
Ebitda RCA |
||
| 422 | 50 | 472 | 1 | 473 | Galp | 908 | (18) | 890 | 3 | 892 |
| 188 | - | 188 | (0) | 188 | E&P | 391 | - | 391 | (0) | 391 |
| 184 | 48 | 232 | 1 | 233 | R&M | 430 | (12) | 418 | 3 | 420 |
| 45 | 1 | 46 | - | 46 | G&P | 74 | (6) | 68 | - | 68 |
| 6 | - | 6 | (0) | 6 | Others | 12 | - | 12 | (0) | 12 |
€m
| Second Quarter | 2016 | First Half | ||||||||
|---|---|---|---|---|---|---|---|---|---|---|
| Ebitda IFRS |
Inventory Ebitda effect RC |
Non recurring items |
Ebitda RCA |
Ebitda IFRS |
Inventory effect |
Ebitda RC |
Non recurring items |
Ebitda RCA |
||
| 366 | (36) | 330 | 7 | 337 | Galp | 530 | 79 | 609 | 22 | 631 |
| 82 | - | 82 | 5 | 86 | E&P | 124 | - | 124 | 11 | 135 |
| 177 | (38) | 139 | 4 | 143 | R&M | 207 | 71 | 278 | 13 | 291 |
| 98 | 2 | 100 | (2) | 97 | G&P | 181 | 8 | 189 | (2) | 187 |
| 10 | - | 10 | 0 | 10 | Others | 17 | - | 17 | 1 | 18 |
€m
| Second Quarter | 2017 | First Half | ||||||||
|---|---|---|---|---|---|---|---|---|---|---|
| Ebit IFRS |
Inventory effect |
Ebit RC |
Non recurring items |
Ebit RCA |
Ebit IFRS |
Inventory effect |
Ebit RC |
Non recurring items |
Ebit RCA |
|
| 199 | 50 | 249 | 4 | 253 | Galp | 485 | (18) | 467 | 6 | 473 |
| 59 | - | 59 | 4 | 63 | E&P | 168 | - | 168 | 2 | 169 |
| 96 | 48 | 144 | 1 | 145 | R&M | 245 | (12) | 233 | 6 | 239 |
| 39 | 1 | 41 | (1) | 40 | G&P | 62 | (6) | 56 | (1) | 55 |
| 5 | - | 5 | (0) | 5 | Others | 10 | - | 10 | (0) | 10 |
€m
| Second Quarter | 2016 | First Half | ||||||||
|---|---|---|---|---|---|---|---|---|---|---|
| Ebit IFRS |
Inventory effect |
Ebit RC |
Non recurring items |
Ebit RCA |
Ebit IFRS |
Inventory effect |
Ebit RC |
Non recurring items |
Ebit RCA |
|
| 131 | (36) | 95 | 90 | 185 | Galp | 128 | 79 | 207 | 116 | 323 |
| (62) | - | (62) | 86 | 24 | E&P | (93) | - | (93) | 95 | 2 |
| 103 | (38) | 65 | 6 | 71 | R&M | 56 | 71 | 126 | 23 | 149 |
| 82 | 2 | 84 | (3) | 81 | G&P | 151 | 8 | 159 | (3) | 156 |
| 9 | - | 9 | 0 | 9 | Others | 15 | - | 15 | 1 | 16 |
| €m | |||||
|---|---|---|---|---|---|
| Quarter | Fist Half | ||||
| 2Q16 | 1Q17 | 2Q17 | 2016 | 2017 | |
| 7.0 | 1.3 | 1.2 | Non-recurring items impacting Ebitda | 22.0 | 2.6 |
| (2.2) | 0.0 | 0.0 | Accidents caused by natural events and insurance compensation | (2.2) | 0.0 |
| (0.2) | (0.1) | (0.6) | Gains/losses on disposal of assets | (0.7) | (0.7) |
| 0.6 | 0.1 | (0.1) | Asset write-offs | 0.6 | 0.0 |
| 4.7 | - | - | Employee restructuring charges | 9.7 | - |
| 4.1 | - | - | Compensation early termination agreement for service and equipment | 10.0 | - |
| - | 1.4 | 1.9 | Litigation costs | 4.5 | 3.2 |
| 82.9 | 0.4 | 3.2 | Non-recurring items impacting non-cash costs | 93.7 | 3.6 |
| 5.4 | 0.0 | 1.1 | Provisions for environmental charges and others | 5.5 | 1.1 |
| 77.4 | 0.4 | 2.1 | Asset impairments | 88.2 | 2.5 |
| 5.3 | (17.9) | 3.8 | Non-recurring items impacting financial results | 19.4 | (14.1) |
| 5.3 | (17.9) | 3.8 | Gains/losses on financial investments | 19.4 | (14.1) |
| 3.4 | 34.2 | 8.2 | Non-recurring items impacting taxes | 43.2 | 42.4 |
| (2.4) | (0.9) | (0.6) | Income taxes on non-recurring items | (7.8) | (1.5) |
| 5.8 | 35.2 | 8.8 | Energy sector contribution taxes | 51.0 | 43.9 |
| (0.2) | 0.1 | 0.1 | Non-controlling interests | (0.2) | 0.2 |
| 98.4 | 18.1 | 16.5 | Total non-recurring items | 178.1 | 34.6 |
| € m | |||||
|---|---|---|---|---|---|
| Quarter | First Half | ||||
| 2Q16 | 1Q17 | 2Q17 | 2016 | 2017 | |
| 3,110 | 3,684 | 3,630 | Sales | 5,751 | 7,314 |
| 157 | 160 | 149 | Services rendered | 329 | 309 |
| 34 | 28 | 28 | Other operating income | 52 | 56 |
| 3,301 | 3,872 | 3,807 | Total operating income | 6,133 | 7,679 |
| (2,518) | (2,908) | (2,914) | Inventories consumed and sold | (4,788) | (5,822) |
| (314) | (377) | (385) | Materials and services consumed | (623) | (762) |
| (78) | (79) | (70) | Personnel costs | (158) | (150) |
| (25) | (23) | (15) | Other operating costs | (34) | (37) |
| (2,935) | (3,387) | (3,385) | Total operating costs | (5,603) | (6,771) |
| 366 | 485 | 422 | Ebitda | 530 | 908 |
| (221) | (194) | (221) | Amortisation, depreciation and impairments | (383) | (415) |
| (14) | (5) | (2) | Provision and impairment of receivables | (19) | (7) |
| 131 | 286 | 199 | Ebit | 128 | 485 |
| 19 | 50 | 37 | Net income from associated companies | 26 | 87 |
| 15 | (12) | (10) | Financial results | 18 | (22) |
| 5 | 8 | 7 | Interest income | 11 | 15 |
| (33) | (29) | (26) | Interest expenses | (67) | (55) |
| 25 | 24 | 27 | Interest capitalised | 46 | 51 |
| (0) | (3) | (10) | Exchange gain (loss) | (7) | (13) |
| 23 | (4) | (4) | Mark-to-market of hedging derivatives | 44 | (7) |
| (4) | (7) | (4) | Other financial costs/income | (9) | (12) |
| 165 | 324 | 226 | Income before taxes | 172 | 550 |
| (82) | (136) | (105) | Taxes1 | (93) | (241) |
| (6) | (35) | (9) | Energy sector contribution taxes2 | (51) | (44) |
| 78 | 153 | 112 | Income before non-controlling interests | 29 | 265 |
| (12) | (19) | (12) | Profit attributable to non-controlling interests | (21) | (31) |
| 66 | 134 | 99 | Net income | 8 | 234 |
1Includes corporate income taxes and taxes payable on oil and gas production, namely Special Participation Tax (Brazil) and IRP (Angola). 2 Includes €16.3 m, €17.0 m and €10.6 m related to the CESE I, CESE II and Fondo Eficiencia Energética, respectively, in the first half of 2017.
| €m | |||
|---|---|---|---|
| 31 December, | 31 March, | 30 June, | |
| 2016 | 2017 | 2017 | |
| Assets | |||
| Non-current assets | |||
| Tangible fixed assets | 5,910 | 6,021 | 5,693 |
| Goodwill | 87 | 86 | 85 |
| Other intangible fixed assets | 268 | 266 | 258 |
| Investments in associates | 1,432 | 1,501 | 1,391 |
| Investments in other participated companies | 3 | 3 | 3 |
| Receivables | 247 | 261 | 246 |
| Deferred tax assets | 335 | 317 | 339 |
| Financial investments | 26 | 26 | 31 |
| Total non-current assets | 8,307 | 8,481 | 8,046 |
| Current assets | |||
| Inventories1 | 869 | 1,049 | 894 |
| Trade receivables | 1,041 | 1,077 | 959 |
| Receivables | 556 | 530 | 457 |
| Loan to Sinopec | 610 | 561 | 527 |
| Financial investments | 19 | 13 | 12 |
| Cash and equivalents | 1,033 | 959 | 1,020 |
| Sub-total current assets | 4,128 | 4,189 | 3,869 |
| Non-current assets held for sale | 4 | - | - |
| Total current assets | 4,132 | 4,189 | 3,869 |
| Total assets | 12,439 | 12,671 | 11,915 |
| Equity and liabilities | |||
| Equity | |||
| Share capital | 829 | 829 | 829 |
| Share premium | 82 | 82 | 82 |
| Translation reserve | 404 | 386 | 41 |
| Other reserves | 2,687 | 2,687 | 2,687 |
| Hedging reserves | 4 | 5 | 5 |
| Retained earnings | 795 | 973 | 776 |
| Profit attributable to equity holders of the parent | 179 | 134 | 234 |
| Equity attributable to equity holders of the parent | 4,980 | 5,097 | 4,654 |
| Non-controlling interests | 1,563 | 1,577 | 1,464 |
| Total equity | 6,543 | 6,674 | 6,118 |
| Liabilities | |||
| Non-current liabilities | |||
| Bank loans and overdrafts | 912 | 885 | 971 |
| Bonds | 1,666 | 1,297 | 1,097 |
| Other payables2 | 305 | 301 | 297 |
| Retirement and other benefit obligations | 359 | 359 | 348 |
| Liabilities from financial leases | 0 | 0 | 0 |
| Deferred tax liabilities | 66 | 69 | 99 |
| Other financial instruments | 1 | 3 | 10 |
| Provisions | 429 | 565 | 558 |
| Total non-current liabilities | 3,738 | 3,479 | 3,380 |
| Current liabilities | |||
| Bank loans and overdrafts | 308 | 284 | 242 |
| Bonds | 17 | 388 | 566 |
| Trade payables | 850 | 837 | 726 |
| Other payables3 | 884 | 883 | 811 |
| Other financial instruments | 17 | 10 | 18 |
| Income tax payable | 75 | 115 | 55 |
| Sub-total current liabilities | 2,152 | 2,517 | 2,418 |
| Non-current liabilities associated with non-current assets held for sale | 5 | - | - |
| Total current liabilities | 2,157 | 2,517 | 2,418 |
| Total liabilities | 5,896 | 5,996 | 5,797 |
| Total equity and liabilities | 12,439 | 12,671 | 11,915 |
1Includes €91 m in inventories from third parties on 30 June 2017.
2 Includes €165 m long-term loan from Sinopec to subsidiary Petrogal Brasil on 30 June 2017.
3 Includes €14 m in advance payments related to inventory from third parties on 30 June 2017.
Galp's consolidated financial statements have been prepared in accordance with IFRS, and subject to limited review. The financial information in the consolidated income statement is reported for the quarters ended on 30 June 2017 and 2016, and 31 March 2017. The financial information in the consolidated financial position is reported on 30 June 2017 and on 31 December 2016.
Galp's financial statements are prepared in accordance with IFRS, and the cost of goods sold is valued at weighted-average cost. When goods and commodity prices fluctuate, the use of this valuation method may cause volatility in results through gains or losses in inventories, which do not reflect the Company's operating performance. This is called the inventory effect.
Another factor that may affect the Company's results, without being an indicator of its true performance, is the set of non-recurring items, namely gains or losses on the disposal of assets, impairments or reinstatements of fixed assets, and environmental or restructuring charges.
For the purpose of evaluating Galp's operating performance, RCA profit measures exclude nonrecurring items and the inventory effect, the latter because the cost of goods sold and materials consumed has been calculated according to the Replacement Cost (RC) valuation method.
Effective on 1 January 2017, exploration expenses written-off in the E&P business are considered as recurring items.
Effective on 1 October 2016, the contribution of the trading activity of oil produced, which was previously accounted for in the R&M business, has been accounted for in the E&P business.
During the fourth quarter of 2016, the operating life of some refining assets was revised, contributing to an increase in depreciation and amortisation charges starting from the second half of 2016.
The benchmark refining margin is calculated with the following weighting: 45% hydrocracking margin + 42.5% cracking margin + 7% base oils + 5.5% Aromatics.
45% Rotterdam Hydrocraking margin: -100% Brent dated, +2.2% LPG FOB Seagoing (50% Butane + 50% Propane), +19.1% EuroBob NWE FOB Bg, +8.7% Naphtha NWE FOB Bg, +8.5% Jet NWE CIF, +45.1% ULSD 10 ppm NWE CIF, +9.0% LSFO 1% FOB Cg; C&L: 7.4%; Terminal rate: \$1/ton; Ocean loss: 0.15% over Brent; Freight 2017: WS Aframax (80 kts) Route Sullom Voe / Rotterdam – Flat \$7.66/ton. Yields in % of weight.
42.5% Rotterdam cracking margin: -100% Brent dated, +2.3% LPG FOB Seagoing (50% Butane + 50% Propane), +25.4% EuroBob NWE FOB Bg, +7.5% Naphtha NWE FOB Bg, +8.5% Jet NWE CIF, +33.3% ULSD 10 ppm NWE CIF, +15.3% LSFO 1% FOB Cg; C&L: 7.7%; Terminal rate: \$1/ton; Ocean loss: 0.15% over Brent; Freight 2017: WS Aframax (80 kts) Route Sullom Voe / Rotterdam – Flat \$7.66/ton. Yields in % of weight.
7% Rotterdam Base Oil margin: -100% Arabian Light, +3.5% LGP FOB Seagoing (50% Butane + 50% Propane), +13% Naphtha NWE FOB Bg, +4.4% Jet NWE CIF, 34% ULSD 10 ppm NWE CIF, +4.5% VGO 1.6% NWE FOB Cg,+ 14% Base Oils FOB, +26% HSFO 3.5% NWE Bg; Consumptions: -6.8% LSFO 1% CIF NWE Cg; C&L: 7.4%; Terminal rate: \$1/ton; Ocean loss: 0.15% over Arabian Light; Freight 2017: WS Aframax (80 kts) Route Sullom Voe / Rotterdam – Flat \$7.66/ton. Yields in % of weight.
5.5% Rotterdam aromatics margin: -60% EuroBob NWE FOB Bg, -40% Naphtha NWE FOB Bg, +37% Naphtha NWE FOB Bg, +16.5% EuroBob NWE FOB Bg, +6.5% Benzene Rotterdam FOB Bg, +18.5% Toluene Rotterdam FOB Bg, +16.6% Paraxylene Rotterdam FOB Bg, +4.9% Ortoxylene Rotterdam FOB Bg; Consumption: -18% LSFO 1% CIF NEW. Yields in % of weight.
According to this method of valuing inventories, the cost of goods sold is valued at the cost of replacement, i.e. at the average cost of raw materials on the month when sales materialise irrespective of inventories at the start or end of the period. The Replacement Cost Method is not accepted by the Portuguese IFRS and is consequently not adopted for valuing inventories. This method does not reflect the cost of replacing other assets.
In addition to using the replacement cost method, RCA items exclude non-recurrent events such as capital gains or losses on the disposal of assets, impairment or reinstatement of fixed assets and environmental or restructuring charges which may affect the analysis of the Company's profit and do not reflect its operational performance.
Results second quarter 2017 July 31, 2017
APETRO: Associação Portuguesa de Empresas Petrolíferas (Portuguese association of oil companies) bbl: barrel of oil BBLT: Benguela-Belize-Lobito-Tomboco Bg: Barges bn: billion boe: barrels of oil equivalent CESE: Contribuição Extraordinária sobre o Sector Energético (Portuguese Extraordinary Energy Sector Contribution) Cg: Cargoes CIF: Costs, Insurance and Freights CORES: Corporación de Reservas Estratégicas de Produtos Petrolíferos COOEC: Offshore Oil Engineering Co. Ltd. CTA: Cumulative Translation Adjustment D&P: Development & Production E&P: Exploration & Production Ebit Earnings before interest and taxes Ebitda: Ebit plus depreciation, amortisation and provisions EUR/€: Euro FLNG: floating liquefied natural gas unit FOB: Free on Board FPSO: Floating, production, storage and offloading unit Galp, Company or Group: Galp Energia, SGPS, S.A., subsidiaries and participated companies G&P: Gas & Power GGND: Galp Gás Natural Distribuição, S.A.
GWh Gigawatt per hour IAS: International Accounting Standards IFRS: International Financial Reporting Standards IRP: Oil income tax (Oil tax payable in Angola) ISP: Tax on oil products k: thousand kboepd: thousands of barrels of oil equivalent per day kbpd: thousands of barrels of oil per day LNG: liquid natural gas LSFO: low sulphur fuel oil m: million mmbbl: millions of barrels mmboe: millions of barrels of oil equivalent mmbtu: million British thermal units mm³: million cubic metres mton: millions of tonnes MW: megawatt NBP: National Balancing Point NG: natural gas n.m.: not meaningful NWE: Northwestern Europe OPEC: Organisation of Petroleum Exporting Countries R&M: Refining & Marketing RC: Replacement Cost RCA: Replacement Cost Adjusted T: tonnes TL: Tômbua-Lândana USA: United States of America USD/\$: Dollar of the United States of America VAT: value-added tax YoY: year-on-year
This report has been prepared by Galp Energia SGPS, S.A. ("Galp" or the "Company") and may be amended and supplemented.
This report does not constitute or form part of and should not be construed as, an offer to sell or issue or the solicitation of an offer to buy or otherwise acquire securities of the Company or any of its subsidiaries or affiliates in any jurisdiction or an inducement to enter into investment activity in any jurisdiction. Neither this report nor any part thereof, nor the fact of its distribution, shall form the basis of, or be relied on in connection with, any contract or commitment or investment decision whatsoever in any jurisdiction.
This report may include forward-looking statements. Forward-looking statements are statements other than in respect of historical facts. The words "believe", "expect", "anticipate", "intends", "estimate", "will", "may", "continue", "should" and similar expressions usually identify forward-looking statements. Forward-looking statements may include statements regarding: objectives, goals, strategies, outlook and growth prospects; future plans, events or performance and potential for future growth; liquidity, capital resources and capital expenditures; economic outlook and industry trends; energy demand and supply; developments of Galp's markets; the impact of regulatory initiatives; and the strength of Galp's competitors.
The forward-looking statements in this report are based upon various assumptions, many of which are based, in turn, upon further assumptions, including without limitation, management's examination of historical operating trends, data contained in the Company's records and other data available from third parties. Although Galp believes that these assumptions were reasonable when made, these assumptions are inherently subject to significant known and unknown risks, uncertainties, contingencies and other important factors which are difficult or impossible to predict and are beyond its control. No assurance, however, can be given that such expectations will prove to have been correct. Important factors that may lead to significant differences between the actual results and the statements of expectations about future events or results include the Company's business strategy, industry developments, financial market conditions, uncertainty of the results of future projects and operations, plans, objectives, expectations and intentions, among others. Such risks, uncertainties, contingencies and other important factors could cause the actual results of Galp or the industry to differ materially from those results expressed or implied in this report by such forward-looking statements.
Real future income, both financial and operating; an increase in demand and change to the energy mix; an increase in production and changes to Galp's portfolio; the amount and various costs of capital, future distributions; increased resources and recoveries; project plans, timing, costs and capacities; efficiency gains; cost reductions; integration benefits; ranges and sale of products; production rates; and the impact of technology can differ substantially due to a number of factors. These factors may include changes in oil or gas prices or other market conditions affecting the oil, gas, and petrochemical industries; reservoir performance; timely completion of development projects; war and other political or security disturbances; changes in law or government regulation, including environmental regulations and political sanctions; the outcome of commercial negotiations; the actions of competitors and customers; unexpected technological developments; general economic conditions, including the occurrence and duration of economic recessions; unforeseen technical difficulties; and other factors.
The information, opinions and forward-looking statements contained in this report speak only as at the date of this report, and are subject to change without notice. Galp and its respective representatives, agents, employees or advisors do not intend to, and expressly disclaim any duty, undertaking or obligation to, make or disseminate any supplement, amendment, update or revision to any of the information, opinions or forward-looking statements contained in this report to reflect any change in events, conditions or circumstances.
Pedro Dias, Head Otelo Ruivo, IRO Cátia Lopes João G. Pereira João P. Pereira Teresa Rodrigues
Tel: +351 21 724 08 66 Fax: +351 21 724 29 65
Address: Rua Tomás da Fonseca, Torre A, 1600-209 Lisboa, Portugal Website: www.galp.com Email:[email protected]
Reuters: GALP.LS Bloomberg: GALP PL
Building tools?
Free accounts include 100 API calls/year for testing.
Have a question? We'll get back to you promptly.