GeoPark Reports First Quarter 2023 Results
Consistent Free Cash Flow From Profitable Barrels Funded a Stronger Balance Sheet and Increased Shareholder Returns
BOGOTA, Colombia–(BUSINESS WIRE)–GeoPark Limited (“GeoPark” or the “Company”) (NYSE: GPRK), a leading independent Latin American oil and gas explorer, operator and consolidator reports its consolidated financial results for the three-month period ended March 31, 2023 (“First Quarter” or “1Q2023”). A conference call to discuss 1Q2023 financial results will be held on May 4, 2023 at 10:00 am (Eastern Daylight Time).
All figures are expressed in US Dollars and growth comparisons refer to the same period of the prior year, except when specified. Definitions and terms used herein are provided in the Glossary at the end of this document. This release does not contain all of the Company’s financial information and should be read in conjunction with GeoPark’s consolidated financial statements and the notes to those statements for the period ended March 31, 2023, available on the Company’s website.
FIRST QUARTER 2023 HIGHLIGHTS
Oil and Gas Production
- Consolidated average oil and gas production of 36,578 boepd, below its production potential of approximately 39,500-40,500 boepd, as previously announced on March 8, 2023, mainly due to temporarily shut-in production and localized blockades in the CPO-5 block (GeoPark non-operated, 30% WI) in Colombia
Revenue, Adjusted EBITDA, Cash Flow & Net Profit
- Revenue of $182.5 million
- Adjusted EBITDA of $114.9 million (a 63% adjusted EBITDA margin)
- Operating profit of $76.6 million (a 42% operating profit margin)
- Cash flow from operations of $91.9 million
- Net profit of $26.3 million ($0.45 basic earnings per share)
Cost and Capital Efficiency as Key Differentiators
- Despite inflationary pressures, combined G&A and G&G decreased by 6% to $11.9 million
- Capital expenditures of $45.0 million
- 1Q2023 adjusted EBITDA to capital expenditures ratio of 2.5x
- Last twelve-month return on capital employed (ROCE) of 62%1
Lower Interest Payments and a Strengthened Balance Sheet
- 1Q2023 interest payments decreased to $13.8 million (from $19.2 million), after reducing gross debt by $275 million from April 2021 to December 2022
- Net leverage of 0.7x and no principal debt maturities until 2027
- Cash in hand of $145.4 million ($128.8 million as of December 31, 2022)
Delivering on Shareholder Returns
- Share buybacks increased by 142% to $7.5 million (acquired 0.6 million shares, over 1% of shares outstanding)
- Cash dividends increased by 55% to $7.5 million (representing an annualized dividend of approximately $30 million, or a 5% dividend yield2)
- Quarterly cash dividend of $0.13 per share, or approximately $7.5 million, payable on May 31, 2023
Enhanced ESG Performance
- Published the 2022 SPEED/ESG Report on April 26, 2023, available on the Company’s website
- 2022 emissions intensity decreased by 34% to 12.1 kg CO2e/boe3 (or a 40% decrease to 9.7 kg CO2e/boe in core Llanos 34 block) mainly due to the interconnection of the Llanos 34 block to Colombia’s national power grid and the start of operations of the solar plant among other initiatives
- Over 240,000 beneficiaries of the Company’s social and environmental programs in 2022
- Women hold 50% of GeoPark’s senior executive positions
Portfolio Management
- Commercial negotiations are ongoing with ENAP, the oil offtaker in Chile, in an effort to resume shut-in production of approximately 400 bopd
- Implemented a restructuring initiative in Chile in April 2023 to provide further cost reductions, in conjunction with a process to evaluate farm-out/divestment opportunities
2023 Work Program: Revised Production and Capital Expenditures Guidance
- Full-year 2023 production guidance has been revised down to 38,000-40,000 boepd mainly due to temporarily shut-in production in the CPO-5 block, and to a lesser extent, due to shut-in production in Chile and deferral of certain drilling activities in Ecuador
- 2H2023 production is expected to average 39,000-42,000 boepd (excluding the potential production from the 2023 exploration drilling program)
- Capital expenditures have been revised down to $180-200 million (from $200-220 million)
- At $80-904 per bbl Brent, GeoPark expects to generate an Adjusted EBITDA of $490-560 million5 and a free cash flow of $120-140 million6
- Targeting to return approximately 40-50% of free cash flow after taxes to shareholders
Upcoming Catalysts
- Drilling 10-12 gross wells in 2Q2023, targeting development and exploration projects in the Llanos basin in Colombia
- Exploration drilling includes 2-3 new gross wells in the Llanos basin (Llanos 123 and Llanos 124 blocks)
Andrés Ocampo, Chief Executive Officer of GeoPark, said: “Despite the challenges faced during the first quarter, GeoPark has been able to deliver strong results, as well as to adapt quickly by reducing costs and streamlining capital expenditures to maximize and protect our cash flow generation, which allow us to continue strengthening our balance sheet and returning more value to our shareholders. For the remainder of 2023, we look forward to continue executing and delivering on our ambitious 2023 work program to grow our production base and drill low-cost and low-risk exploration targets with the main focus on our core Llanos basin.”
CONSOLIDATED OPERATING PERFORMANCE
Key performance indicators:
|
Key Indicators |
1Q2023 |
|
4Q2022 |
|
1Q2022 |
|
|||
|
Oil productiona (bopd) |
33,801 |
|
35,451 |
|
34,442 |
|
|||
|
Gas production (mcfpd) |
16,664 |
|
17,886 |
|
25,096 |
|
|||
|
Average net production (boepd) |
36,578 |
|
38,433 |
|
38,626 |
|
|||
|
Brent oil price ($ per bbl) |
82.5 |
|
88.8 |
|
96.9 |
|
|||
|
Combined realized price ($ per boe) |
61.3 |
|
68.5 |
|
75.8 |
|
|||
|
⁻ Oil ($ per bbl) |
66.7 |
|
73.7 |
|
84.3 |
|
|||
|
⁻ Gas ($ per mcf) |
4.6 |
|
5.0 |
|
4.8 |
|
|||
|
Sale of crude oil ($ million) |
175.1 |
|
220.7 |
|
239.0 |
|
|||
|
Sale of purchased crude oil ($ million) |
0.8 |
|
3.1 |
|
– |
|
|||
|
Sale of gas ($ million) |
6.5 |
|
7.1 |
|
10.2 |
|
|||
|
Revenue ($ million) |
182.5 |
|
231.0 |
|
249.2 |
|
|||
|
Commodity risk management contracts b ($ million) |
0.0 |
|
0.5 |
|
(78.1 |
) |
|||
|
Production & operating costsc ($ million) |
(52.5 |
) |
(77.0 |
) |
(80.6 |
) |
|||
|
G&G, G&Ad ($ million) |
(11.9 |
) |
(17.4 |
) |
(12.7 |
) |
|||
|
Selling expenses ($ million) |
(2.4 |
) |
(2.8 |
) |
(2.0 |
) |
|||
|
Operating profit ($ million) |
76.6 |
|
81.7 |
|
58.6 |
|
|||
|
Adjusted EBITDA ($ million) |
114.9 |
|
132.1 |
|
122.6 |
|
|||
|
Adjusted EBITDA ($ per boe) |
38.6 |
|
39.2 |
|
37.3 |
|
|||
|
Net profit ($ million) |
26.3 |
|
52.2 |
|
31.0 |
|
|||
|
Capital expenditures ($ million) |
45.0 |
|
53.6 |
|
39.4 |
|
|||
|
Cash and cash equivalents ($ million) |
145.4 |
|
128.8 |
|
114.1 |
|
|||
|
Short-term financial debt ($ million) |
5.7 |
|
12.5 |
|
8.7 |
|
|||
|
Long-term financial debt ($ million) |
485.9 |
|
485.1 |
|
633.9 |
|
|||
|
Net debt ($ million) |
346.2 |
|
368.8 |
|
528.4 |
|
|||
|
Dividends paid ($ per share) |
0.130 |
|
0.127 |
|
0.082 |
|
|||
|
Shares repurchased (million shares) |
0.642 |
|
0.942 |
|
0.232 |
|
|||
|
Basic shares – at period end (million shares) |
57.596 |
|
57.622 |
|
60.016 |
|
|||
|
Weighted average basic shares (million shares) |
57.853 |
|
58.261 |
|
60.090 |
|
|
a) |
Includes royalties paid in kind in Colombia for approximately 1,665, 759 and 1,115 bopd in 1Q2023, 4Q2022 and 1Q2022, respectively. No royalties were paid in kind in other countries. Production in Ecuador is reported before the Government’s production share. |
|
b) |
Please refer to the Commodity Risk Management Contracts section below. |
|
c) |
Production and operating costs include operating costs, royalties and economic rights paid in cash, share based payments and purchased crude oil. |
|
d) |
G&A and G&G expenses include non-cash, share-based payments for $1.4 million, $3.3 million and $0.9 million in 1Q2023, 4Q2022 and 1Q2022, respectively. These expenses are excluded from the adjusted EBITDA calculation. |
REVISED 2023 PRODUCTION GUIDANCE
As announced on March 8 and April 11, 2023, GeoPark’s 2023 net production year to date has been below its potential of approximately 39,500-40,500 boepd, mainly due to: (i) temporarily shut-in production of the Indico 6 and Indico 7 wells in the CPO-5 block in Colombia for approximately 2,400-3,300 bopd net to GeoPark, and to a lesser extent (ii) shut-in production of approximately 400 bopd in Chile due to ongoing commercial negotiations with ENAP, the oil offtaker, and (iii) the delay of certain drilling activities in Ecuador.
GeoPark’s previous 2023 production guidance was based on the CPO-5 block’s operator expectation that shut-in barrels were going to be back on production in early 2Q2023. Now, those barrels are not expected to be back before July 2023.
As a result, GeoPark had to revise its 2023 annual average production guidance down to 38,000-40,000 boepd (from 39,500-41,500 boepd). Assuming production in the CPO-5 block is normalized in early 3Q2023, GeoPark’s production in 2H2023 is expected to average 39,000-42,000 boepd.
The Indico 6 and Indico 7 wells were drilled in late 2022 and together tested over 11,000 bopd gross (or 3,300 bopd net to GeoPark) and are expected to stabilize production at approximately 8,000 bopd gross (or 2,400 bopd net to GeoPark). These two wells were shut-in (Indico 6 in December 2022 and Indico 7 in early January 2023) after the regulator (ANH) requested that the CPO-5 block operator temporarily suspend production from these wells until definite surface facilities are completed.
GeoPark also adjusted its 2023 capital expenditures down to $180-200 million (from $200-220 million) combining cost efficiencies and the deferral of certain projects in Colombia and Ecuador, which allows GeoPark to maintain its free cash flow guidance.
The table below provides further details about GeoPark’s revised 2023 guidance compared to its previous 2023 guidance.
|
|
May 3, 2023 |
Previous 2023 |
|
Brent Assumption ($ per bbl) |
$80-907 |
$80-90 |
|
2023 Annual Average Production (boepd) |
38,000-40,000 |
39,500-41,500 |
|
Adjusted EBITDA8 |
$490-560 million |
$510-580 million |
|
2023 Capital Expenditures |
$180-200 million |
$200-220 million |
|
Cash Income Taxes* |
$150-210 million |
$150-210 million |
|
Interest Payments |
$27-30 million |
$27-30 million |
|
Free Cash Flow |
$120-140 million |
$120-140 million |
|
(*) Cash taxes include GeoPark’s estimates of the impact of the new tax reform in Colombia, irrespective of the timing of its cash impact, expected in 2023 or early 2024. |
Production: Oil and gas production in 1Q2023 was 36,578 boepd. Adjusting for divestments in Argentina (completed on January 31, 2022), consolidated oil and gas production decreased by 4% compared to 1Q2022, due to lower production in Colombia, Chile and Brazil, partially offset by higher production in Ecuador.
Since early March 2023, GeoPark shut-in approximately 400 bopd of its oil production in Chile due to ongoing commercial negotiations with the Company’s off-taker, and as a result, Chile is currently producing approximately 1,600-1,800 boepd compared to an average production of 1,988 boepd in 1Q2023.
Oil represented 92% and 89% of total reported production in 1Q2023 and 1Q2022, respectively.
For further details, please refer to the 1Q2023 Operational Update published on April 11, 2023.
Reference and Realized Oil Prices: Brent crude oil prices decreased by 15% to $82.5 per bbl during 1Q2023, and the consolidated realized oil sales price decreased by 21% to $66.7 per bbl in 1Q2023.
A breakdown of reference and net realized oil prices in relevant countries in 1Q2023 and 1Q2022 is shown in the tables below:
|
1Q2023 – Realized Oil Prices ($ per bbl) |
Colombia |
Chile |
Argentina9 |
Ecuador |
||||
|
Brent oil price (*) |
82.5 |
|
82.3 |
|
– |
83.5 |
|
|
|
Local marker differential |
(8.4 |
) |
– |
|
– |
|
– |
|
|
Commercial, transportation discounts & other |
(7.6 |
) |
(8.0 |
) |
– |
|
(12.7 |
) |
|
Realized oil price |
66.5 |
|
74.3 |
|
– |
|
70.8 |
|
|
Weight on oil sales mix |
97.5 |
% |
1.5 |
% |
– |
|
0.7 |
% |
|
1Q2022 – Realized Oil Prices ($ per bbl) |
Colombia |
Chile |
Argentina |
Ecuador |
||||
|
Brent oil price (*) |
96.9 |
|
103.7 |
|
96.9 |
|
– |
|
|
Local marker differential |
(3.7 |
) |
– |
|
– |
|
– |
|
|
Commercial, transportation discounts & other |
(8.8 |
) |
(7.8 |
) |
(40.2 |
) |
– |
|
|
Realized oil price |
84.4 |
|
95.9 |
|
56.7 |
|
– |
|
|
Weight on oil sales mix |
97.8 |
% |
1.1 |
% |
1.0 |
% |
– |
|
|
(*) Corresponds to the average month of sale price ICE Brent for Colombia, Ecuador and Argentina, and Dated Brent for Chile. |
Revenue: Consolidated revenue decreased by 27% to $182.5 million in 1Q2023, compared to $249.2 million in 1Q2022, mainly reflecting lower oil and gas prices and to a lesser extent, lower deliveries.
Sales of crude oil: Consolidated oil revenue decreased by 27% to $175.1 million in 1Q2023, mainly explained by a 21% decrease in realized oil prices and 7% lower deliveries. Oil revenue was 96% of total revenue in 1Q2023 and 1Q2022.
|
(In millions of $) |
1Q2023 |
1Q2022 |
|
Colombia |
170.7 |
234.0 |
|
Chile |
1.2 |
3.1 |
|
Argentina |
– |
1.7 |
|
Brazil |
0.1 |
0.2 |
|
Ecuador |
3.0 |
– |
|
Oil Revenue |
175.1 |
239.0 |
- Colombia: 1Q2023 oil revenue decreased by 27% to $170.7 million, reflecting lower realized oil prices and lower oil deliveries. Realized prices decreased by 21% to $66.5 per bbl due to lower Brent oil prices while oil deliveries decreased by 7% to 29,638 bopd. Earn-out payments decreased to $6.8 million in 1Q2023, compared to $8.4 million in 1Q2022 in line with lower oil prices.
- Chile: 1Q2023 oil revenue decreased by 60% to $1.2 million, reflecting lower realized prices and lower oil deliveries. Realized prices decreased by 22% to $74.3 per bbl due to lower Brent oil prices while oil deliveries decreased by 49% to 185 bopd.
- Ecuador: 1Q2023 oil revenue totaled $3.0 million, reflecting a realized oil price of $70.8 with deliveries of 478 bopd. Deliveries in Ecuador are net of the Government’s production share.
Sales of purchased crude oil: 1Q2023 sales of purchased crude oil totaled $0.8 million, which corresponds to oil trading operations (purchasing and selling crude oil from third parties with the cost of the oil purchased being reflected in production and operating costs).
Sales of gas: Consolidated gas revenue decreased by 36% to $6.5 million in 1Q2023 compared to $10.2 million in 1Q2022 reflecting 33% lower gas deliveries and 4% lower gas prices. Gas revenue was 4% of total revenue in 1Q2023 and 1Q2022.
|
(In millions of $) |
1Q2023 |
1Q2022 |
|
Chile |
3.2 |
3.6 |
|
Brazil |
3.1 |
5.7 |
|
Argentina |
– |
0.3 |
|
Colombia |
0.2 |
0.5 |
|
Gas Revenue |
6.5 |
10.2 |
- Chile: 1Q2023 gas revenue decreased by 10% to $3.2 million, reflecting lower gas deliveries, partially offset by higher gas prices. Gas deliveries fell by 12% to 9,462 mcfpd (1,577 boepd). Gas prices were 2% higher, at $3.8 per mcf ($22.7 per boe) in 1Q2023.
- Brazil: 1Q2023 gas revenue decreased by 45% to $3.1 million, due to lower gas deliveries and lower gas prices. Gas deliveries decreased by 43% from the Manati gas field to 5,626 mcfpd (937 boepd). Gas prices decreased by 4% to $6.2 per mcf ($37.2 per boe) in 1Q2023.
Commodity Risk Management Contracts: Consolidated commodity risk management contracts amounted to zero in 1Q2023, compared to a $78.1 million loss in 1Q2022.
The table below provides a breakdown of realized and unrealized commodity risk management charges in 1Q2023 and 1Q2022:
|
(In millions of $) |
1Q2023 |
1Q2022 |
|
Realized loss |
– |
(30.5) |
|
Unrealized loss |
– |
(47.6) |
|
Commodity risk management contracts |
– |
(78.1) |
In 1Q2023 GeoPark had zero cost collars covering 9,500 bopd with purchased puts with an average price of $66.0 per bbl and sold calls at an average price of $112.6 per bbl.
Please refer to the “Commodity Risk Oil Management Contracts” section below for a description of hedges in place as of the date of this release.
Production and Operating Costs: Consolidated production and operating costs decreased to $52.5 million from $80.6 million, mainly resulting from lower royalties and economic rights due to lower oil prices, partially offset by higher operating costs.
The table below provides a breakdown of production and operating costs in 1Q2023 and 1Q2022:
|
(In millions of $) |
1Q2023 |
1Q2022 |
|
Royalties |
(7.2) |
(14.8) |
|
Economic rights |
(16.1) |
(43.2) |
|
Operating costs |
(28.5) |
(22.5) |
|
Purchased crude oil |
(0.7) |
– |
|
Share-based payments |
(0.0) |
(0.1) |
|
Production and operating costs |
(52.5) |
(80.6) |
Consolidated royalties amounted to $7.2 million in 1Q2023 compared to $14.8 million in 1Q2022, in line with lower oil prices.
Consolidated economic rights (including high price participation, x-factor and other economic rights paid to the Colombian Government) amounted to $16.1 million in 1Q2023 compared to $43.2 million in 1Q2022, in line with lower oil prices.
Consolidated operating costs increased to $28.5 million in 1Q2023 compared to $22.5 million in 1Q2022.
The breakdown of operating costs is as follows:
- Colombia: Total operating costs increased to $24.5 million in 1Q2023 from $16.2 million in 1Q2022, mainly due to higher operating costs per boe, partially offset by lower deliveries (deliveries in Colombia decreased by 7%).
- Chile: Total operating costs decreased to $1.9 million in 1Q2023 from $3.7 million in 1Q2022, in line with lower operating costs per boe and lower oil and gas deliveries (deliveries in Chile decreased by 18%).
- Brazil: Total operating costs decreased to $0.7 million in 1Q2023 compared to $1.2 million in 1Q2022, due to lower gas deliveries from the Manati field (deliveries in Brazil decreased by 43%), partially offset by higher operating costs per boe.
- Ecuador: Total operating costs were $1.3 million in 1Q2023.
- Argentina: The divestment of the Aguada Baguales, El Porvenir and Puesto Touquet blocks was completed in January 2022. The comparative period, 1Q2022, included $1.3 million of operating costs in Argentina.
Consolidated purchased crude oil charges amounted to $0.7 million in 1Q2023, which corresponds to oil trading operations (purchasing and selling crude oil from third parties with the sale of purchased oil being reflected in revenue).
Selling Expenses: Consolidated selling expenses increased to $2.4 million in 1Q2023 compared to $2.0 million in 1Q2022.
Geological & Geophysical Expenses: Consolidated G&G expenses decreased to $2.5 million in 1Q2023 compared to $2.7 million in 1Q2022.
Administrative Expenses: Consolidated G&A decreased to $9.4 million in 1Q2023 compared to $9.9 million in 1Q2022.
Adjusted EBITDA: Consolidated adjusted EBITDA10 decreased by 6% to $114.9 in 1Q2023 (on a per boe basis, adjusted EBITDA increased to $38.6 per boe in 1Q2023 from $37.3 per boe in 1Q2022).
|
(In millions of $) |
1Q2023 |
1Q2022 |
|
Colombia |
113.5 |
121.8 |
|
Chile |
1.5 |
2.1 |
|
Brazil |
1.6 |
3.6 |
|
Argentina |
(0.7) |
(1.7) |
|
Ecuador |
1.0 |
(0.5) |
|
Corporate |
(2.0) |
(2.8) |
|
Adjusted EBITDA |
114.9 |
122.6 |
The table below shows production, volumes sold and the breakdown of the most significant components of adjusted EBITDA for 1Q2023 and 1Q2022, on a per boe basis:
|
Adjusted EBITDA/boe |
Colombia |
|
Chile |
|
Brazil |
|
Ecuador |
|
Totald |
|||||||||||||||||||||
|
|
1Q23 |
|
1Q22 |
|
1Q23 |
|
1Q22 |
|
1Q23 |
|
1Q22 |
|
1Q23 |
|
1Q22 |
|
1Q23 |
|
1Q22 |
|||||||||||
|
Production (boepd) |
32,580 |
|
33,738 |
|
1,988 |
|
2,279 |
|
1,020 |
|
1,815 |
|
990 |
|
190 |
|
36,578 |
|
38,626 |
|
||||||||||
|
Inventories, RIK & Othera |
(2,837 |
) |
(1,635 |
) |
(225 |
) |
(121 |
) |
(65 |
) |
(153 |
) |
(512 |
) |
(190 |
) |
(3,513 |
) |
(2,098 |
) |
||||||||||
|
Sales volume (boepd) |
29,743 |
|
32,103 |
|
1,763 |
|
2,158 |
|
955 |
|
1,662 |
|
478 |
|
– |
|
33,065 |
|
36,528 |
|
||||||||||
|
% Oil |
99.6 |
% |
99.4 |
% |
11 |
% |
17 |
% |
2 |
% |
1 |
% |
100 |
% |
– |
|
92 |
% |
89 |
% |
||||||||||
|
($ per boe) |
|
|
|
|
|
|
|
|
|
|
||||||||||||||||||||
|
Realized oil price |
66.5 |
|
84.4 |
|
74.3 |
|
95.9 |
|
71.2 |
|
104.5 |
|
70.8 |
|
– |
|
66.7 |
|
84.3 |
|
||||||||||
|
Realized gas pricec |
19.2 |
|
28.8 |
|
22.7 |
|
22.3 |
|
37.2 |
|
39.0 |
|
– |
|
– |
|
27.8 |
|
28.8 |
|
||||||||||
|
Earn-out |
(2.5 |
) |
(2.9 |
) |
– |
|
– |
|
– |
|
– |
|
– |
|
– |
|
(2.5 |
) |
(2.9 |
) |
||||||||||
|
Combined Price |
63.8 |
|
81.2 |
|
28.1 |
|
34.6 |
|
37.9 |
|
39.9 |
|
70.8 |
|
– |
|
61.3 |
|
75.8 |
|
||||||||||
|
Realized commodity risk management contracts |
– |
|
(10.6 |
) |
– |
|
– |
|
– |
|
– |
|
– |
|
– |
|
– |
|
(9.3 |
) |
||||||||||
|
Operating costse |
(9.6 |
) |
(5.9 |
) |
(14.0 |
) |
(18.9 |
) |
(11.4 |
) |
(10.6 |
) |
(31.2 |
) |
– |
|
(10.1 |
) |
(7.2 |
) |
||||||||||
|
Royalties & economic rights |
(8.5 |
) |
(19.7 |
) |
(1.0 |
) |
(1.4 |
) |
(3.0 |
) |
(3.2 |
) |
– |
|
– |
|
(7.8 |
) |
(17.7 |
) |
||||||||||
|
Purchased crude oilb |
– |
|
– |
|
– |
|
– |
|
– |
|
– |
|
– |
|
– |
|
(0.2 |
) |
– |
|
||||||||||
|
Selling & other expenses |
(0.7 |
) |
(0.6 |
) |
(0.4 |
) |
(0.4 |
) |
– |
|
– |
|
(9.6 |
) |
– |
|
(0.8 |
) |
(0.6 |
) |
||||||||||
|
Operating Netback/boe |
45.0 |
|
44.3 |
|
12.6 |
|
13.9 |
|
23.4 |
|
26.2 |
|
30.0 |
|
– |
|
42.2 |
|
41.0 |
|
||||||||||
|
G&A, G&G & other |
|
|
|
|
|
|
|
|
(3.6 |
) |
(3.7 |
) |
||||||||||||||||||
|
Adjusted EBITDA/boe |
|
|
|
|
|
|
|
|
38.6 |
|
37.3 |
|
||||||||||||||||||
|
a) RIK (Royalties in kind): Includes royalties paid in kind in Colombia for approximately 1,665 bopd and 1,115 bopd in 1Q2023 and 1Q2022, respectively. No royalties were paid in kind in Chile, Brazil or Ecuador. Production in Ecuador is reported before the Government’s production share. Other includes economic rights paid in kind. |
|
b) Reported in the Corporate business segment. |
|
c) Conversion rate of $mcf/$boe=1/6. |
|
d) Includes amounts recorded in Argentina and corporate segments. |
|
e) Operating costs per boe included in this table include certain adjustments to the reported figures (IFRS 16 and others). |
Depreciation: Consolidated depreciation charges increased to $27.2 million in 1Q2023 compared to $21.6 million in 1Q2022.
Write-off of unsuccessful exploration efforts: The consolidated write-off of unsuccessful exploration efforts amounted to $10.6 million in 1Q2023 and zero in 1Q2022. Amounts recorded in 1Q2023 correspond to unsuccessful exploration efforts in the Llanos 87 block and to a lesser extent, in the Llanos 94 block, both in Colombia.
Other Income (Expenses): Other operating expenses showed a $1.4 million loss in 1Q2023, compared to a $4.5 million gain in 1Q2022.
CONSOLIDATED NON-OPERATING RESULTS AND PROFIT FOR THE PERIOD
Financial Expenses: Net financial expenses decreased to $9.8 million in 1Q2023 from $15.1 million in 1Q2022, mainly resulting from a sustained deleveraging process that started in April 2021 and continued in 2022.
Foreign Exchange: Net foreign exchange losses amounted to $3.4 million in 1Q2023 compared to $6.6 million loss in 1Q2022.
Income Tax: Income taxes totaled $37.1 million in 1Q2023 compared to $5.9 million in 1Q2022, mainly resulting from higher profits before income taxes plus the effect of fluctuations of the Colombian peso and the effects of the tax reform in Colombia applicable in fiscal year 2023.
Net Profit: Net profit decreased to $26.3 million in 1Q2023 compared to $31.0 million in 1Q2022.
BALANCE SHEET
Cash and Cash Equivalents: Cash and cash equivalents totaled $145.4 million as of March 31, 2023, compared to $128.8 million as of December 31, 2022.
This net increase is explained by the following:
|
(In millions of $) |
1Q2023 |
|
Cash flows from operating activities |
91.9 |
|
Cash flows used in investing activities |
(45.0) |
|
Cash flows used in financing activities |
(30.7) |
|
Currency Translation |
0.3 |
|
Net increase in cash & cash equivalents |
16.6 |
Cash flows from operating activities of $91.9 million in 1Q2023 included income tax payments of $6.0 million. In 2Q2023 the Company expects to pay $80-90 million related to tax obligations accrued in the fiscal year 2022.
Cash flows used in financing activities mainly included $13.7 million related to interest payments, $7.5 million related to executing the Company’s share buyback program and $7.5 million related to dividend payments.
Financial Debt: Total financial debt net of issuance cost was $491.6 million, all corresponding to the 2027 Notes. Short-term financial debt was $5.7 million as of March 31, 2023, and correspond to interest accrued on the 2027 Notes.
|
(In millions of $) |
March 31, 2023 |
December 31, 2022 |
|
2027 Notes |
491.6 |
497.6 |
|
Financial debt |
491.6 |
497.6 |
For further details, please refer to Note 12 of GeoPark’s consolidated financial statements as of March 31, 2023, available on the Company’s website.
FINANCIAL RATIOSa
|
(In millions of $) |
|
|
|
|
|
|
|
|
|
|
| Period-end | Financial Debt |
Cash and Cash Equivalents |
Net Debt | Net Debt/LTM Adj. EBITDA |
LTM Interest Coverage |
|||||
|
1Q2022 |
642.5 |
114.1 |
528.4 |
1.5x |
8.4x |
|||||
|
2Q2022 |
585.4 |
|
122.5 |
|
462.9 |
|
1.0x |
|
10.8x |
|
|
3Q2022 |
491.1 |
|
93.0 |
|
398.1 |
|
0.8x |
|
12.7x |
|
|
4Q2022 |
497.6 |
|
128.8 |
|
368.8 |
|
0.7x |
|
14.9x |
|
|
1Q2023 |
491.6 |
|
145.4 |
|
346.2 |
|
0.7x |
|
15.8x |
|
|
a) |
Based on trailing last twelve-month financial results (“LTM”). |
Covenants in the 2027 Notes: The 2027 Notes include incurrence test covenants that, among others, require that the Net Debt to Adjusted EBITDA ratio should not exceed 3.25 times and the Adjusted EBITDA to Interest ratio should exceed 2.5 times.
COMMODITY RISK OIL MANAGEMENT CONTRACTS
The table below summarizes commodity risk management contracts in place as of the
Contacts
INVESTORS:
Stacy Steimel
Shareholder Value Director
T: +562 2242 9600
ssteimel@geo-park.com
Miguel Bello
Market Access Director
T: +562 2242 9600
mbello@geo-park.com
Diego Gully
Investor Relations Director
T: +55 21 99636 9658
dgully@geo-park.com
MEDIA:
Communications Department
communications@geo-park.com
