Frontera Energy Corporation ("Frontera" or the "Company") provided an operational update and announced its full year 2025 capital and production guidance. All values in this news release and the Company's financial disclosures are in United States dollars, unless otherwise noted.
Q4 2024 Operational Update
Colombia and Ecuador Upstream: Q4 2024 production to date is approximately 42,450 boe/d, with a year-to-date average of approximately 40,200 boe/d, within the Company's 2024 production guidance range. CPE-6 achieved another daily production record with close to 9,000 boe/d in December and Q4 2024 production to date for the CPE-6 Block is approximately 8,400 boe/d.
Infrastructure: Puerto Bahia has received the final $10 million disbursement of the accordion related to the construction of the Reficar connection. The Company expects construction for the connection to be completed by year-end 2024. In November 2024, the Company received its final installment of the Oleoducto de los Llanos S.A. ("ODL") declared distributions. The Company received $61.0 million in total distributions in 2024 from its 35% interest in the ODL pipeline.
The Company's strategic alternatives review for its Infrastructure business is ongoing. Since its launch in May 2024, the Company has prepared a virtual data room, held management presentations and engaged in discussions with several interested third parties. The Company is working diligently to conclude its review process and believes that the process is nearing its final stages. Frontera has retained Goldman Sachs & Co. LLC as financial advisor in connection with the strategic alternatives review. There can be no guarantee that this strategic alternative review process will result in a transaction.
Guyana: Notwithstanding recent comments from certain Government officials, Frontera and its joint venture partner CGX Energy Inc. (jointly, "the JV") are firmly of the view that the Corentyne block Petroleum Agreement remains in place. These comments have created confusion amongst stakeholders which have materially affected the JV and caused harm to the JV's efforts to develop the Corentyne block. The JV is reviewing all alternatives to safeguard its interest in the Corentyne block and Guyana and has sent the Government of Guyana a letter activating a sixty (60) day period for the parties to the Corentyne block Petroleum Agreement to make all reasonable efforts to amicably resolve all disputes via negotiation, as provided for in the Corentyne block Petroleum Agreement.
Key 2025 Capital and Production Guidance Highlights:
Frontera expects to deliver a full year production of 41,000 – 43,000 boe/d for 2025, an increase of 2% in production at the midpoint compared to 2024 levels and anticipates generating consolidated Operating EBITDA of $370-$415 million at $75/bbl and $420-$465 million at $80/bbl average Brent prices.
The Company plans to invest $200-$245 million, including $30-$40 million exploration investments, in the Company's core Colombia and Ecuador Upstream business, a 13% decrease at the midpoint compared to 2024.
Frontera expects to deploy $30-$40 million to drill three exploration wells, the high-impact Hidra-1 exploration well in the VIM-1 block, one well in the Llanos 99 block, and one well in the Cachicamo block and to complete additional seismic and pre-drilling activities in Colombia.
The Company will invest $15-$20 million in the Company's standalone and growing Colombia Infrastructure business to complete and commission the Reficar connection, perform maintenance activities in Puerto Bahia and make investments related to the SAARA water management project.
Total production costs, including both production and energy costs, are expected to average $14.00 – $15.00 per boe, a decrease of 3% at the midpoint compared to 2024. Transportation costs for 2025 are forecasted to average $12.50 - $13.00 per boe, an increase of 11% at the midpoint compared to 2024 mainly due to the increase of trucking and pipeline tariffs.
Frontera expects to generate consolidated 2025 Free Cash Flow of $79-$122 million and $124-$167 million at a $75/bbl and $80/bbl average Brent, respectively. 2025 Upstream Free Cash Flow is projected to be between $65-$95 million and $110-$140 million at a $75/bbl and $80/bbl average Brent, respectively.
The Company will consider future additional stakeholder value enhancing initiatives, including additional dividends, distributions, or bond buybacks, based upon overall results of our businesses and the Company's strategic goals.
Orlando Cabrales, Chief Executive Officer (CEO), Frontera, commented:
"Frontera's production has maintained its positive momentum in the second half of 2024, averaging over 42,450 boe/d so far in the fourth quarter. The Company has delivered average production of approximately 40,200 boe/d year to date in 2024 within the Company's Full Year 2024 production guidance range.
Moving on to 2025, Frontera's 2025 capital and production guidance continues to build on the Company's foundational strategy of delivering value over volumes. For 2025, the Company expects to deliver 41,000 to 43,000 boe/d of full year production, generating between $370 to $415 million and $420 to $465 million in consolidated Operating EBITDA at $75/bbl and $80/bbl average Brent price, respectively.
The Company plans to invest between $216 to $268 million in total capital in 2025, a 20% reduction compared at the midpoint of our 2024 guidance. Our 2025 capital and production plan focuses on the most productive and profitable assets in the portfolio, building on the Company's successful heavy asset drilling campaign in 2024 in the Quifa and CPE-6 blocks. Our capital plan is fully funded from our operations and partially protected by our proactive hedging strategy.
We will also invest in our exploration portfolio, led by the drilling of our high-impact Hidra-1 exploration well in the VIM-1 block - originally postponed from our 2024 plan, one well in the Cachicamo block and one well in the Llanos 99 block. This approach aims to unlock growth potential in near field reserves.
Our 2025 Infrastructure business is expected to generate Operating EBITDA between $20 to $35 million, a 38% increase compared at the midpoint of our 2024 guidance, reflecting the positive impact of our investments in Puerto Bahia, including from the ramp-up of the Reficar connection in 2025, and the ramp-up of facilities related to the SAARA reverse osmosis water treatment project reaching our 250,000 barrels of water handled per day target.
Frontera expects to generate between $79 to $122 million in consolidated Free Cash Flow at $75/bbl average Brent prices, an 18% increase compared at the midpoint of our 2024 guidance at $80/bbl. Despite lower expected oil prices, Frontera projects strong cash flow generation driven by higher production, lower capital expenditures and a focus on cost control.
With respect to Guyana, Frontera and its JV partner are firmly of the view that the Corentyne block Petroleum Agreement remains in place. However, the JV recognizes that recent comments from certain Government officials have materially affected the JV and caused harm to JV efforts to develop the Corentyne block. The JV is reviewing all alternatives to safeguard its interest in the Corentyne block and in Guyana.
Frontera remains committed to enhancing stakeholder value initiatives for 2024 and beyond, including the possibility of additional dividends, share buybacks, bond buybacks or other initiatives, based on the overall results of the business, cash flow generation, oil prices and the Company's strategic goals."
Operational Update
Colombia and Ecuador Upstream
Frontera's Q4 2024 production to date is approximately 42,450 boe/d, with a year-to-date average of approximately 40,200 boe/d - within Frontera's full year 2024 production guidance range.
In November 2024, Frontera increased the water handling capacity at its CPE-6 block to 360,000 bwpd, and as a result, in December, the Company achieved a new daily production record of close to 9,000 boe/d from the block.
With respect to our SAARA water management project, Frontera processed an average of 135,000 barrels of water per day in November and peaked at 185,000 barrels of water per day. The Company remains focused on reaching the Company's goal of processing 250,000 barrels supporting higher production levels in the Quifa block.
On the exploration front, 2024 remained a challenging year for the Company's Colombia and Ecuador Upstream business. Due to social issues, the spudding of the high-impact Hidra-1 well on the VIM-1 block, while drill-ready, was paused and the well is now slated to be drilled in the first half of 2025. Preliminary results from our seismic activities related to the LLA-119 block were below the Company's expectations and the Company is currently reviewing its alternatives related to this block. Additionally, the Company expects to drill its final exploration well for 2024, the Papilio-1 well, targeting near field targets on the Cachicamo block in Colombia in December with results expected during the first quarter of 2025.
Infrastructure
Puerto Bahia has drawn the final $10 million disbursement of the $30 million accordion of the Pipeline Investment Limited ("PIL") loan facility to fund the construction of the connection project between Puerto Bahia's liquids port facility and the Cartagena refinery operated by Refineria de Cartagena S.A.S. ("Reficar"). The connection construction is 73% complete and is scheduled for completion by the end of 2024. The Reficar connection is expected to be operational in early 2025. Puerto Bahia expects the first crude oil import vessel to reach Reficar through the connection in February 2025.
On November 21, 2024, PIL received the final 2024 ODL distribution payment of $8.9 million. The Company has received total full year 2024 distributions of $61.0 million from its 35% interest in the ODL pipeline. The Company expects the total debt outstanding at PIL, inclusive of the $30 million Reficar connection project accordion, to be $101 million on December 31, 2024, following its scheduled amortization payment and cash flow sweep on December 15, 2024. This represents a $30 million debt reduction during fiscal year 2024 and a total $50 million debt reduction since the PIL loan facility first closed in March 2023.
Guyana
As highlighted during Frontera's Q3 2024 conference call, the Company and its joint venture partner CGX Energy Inc. remain committed to the potential development of the Corentyne block as supported by the JV's recent discoveries at Kawa-1 and Wei-1.
The JV has engaged in ongoing constructive communications with the Government of Guyana regarding the Corentyne Block with the latest one occurring on September 25th, 2024. To date, the JV has not received any formal communications from the Government of Guyana regarding the status of the license. The JV is firmly of the view that the Corentyne block Petroleum Agreement remains in place. The JV recognizes that recent comments from certain Government officials have created confusion amongst stakeholders which have materially affected the JV and caused harm to the JV's efforts to develop the Corentyne block.
The JV is reviewing all alternatives to safeguard its interest in the Corentyne block and Guyana and has sent the Government of Guyana a letter activating a sixty (60) day period for the parties to the Corentyne block Agreement to make all reasonable efforts to amicably resolve all disputes via negotiation, as provided for in the Corentyne block Petroleum Agreement.
About Frontera's 2025 Capital, Production and Cash Flow Guidance
Frontera's 2025 capital and production guidance is based on an average Brent price of $75-$80/bbl, an average sales price oil differential of $4.50/bbl, and an exchange rate of 4,250 Colombian Pesos per US dollar in 2025.
Other key 2025 guidance highlights include:
Estimated $50-$60 million in distributions to be received for the Company's interest in the ODL pipeline.
Debt service payments are estimated to be approximately $45-$55 million for 2025, including a payment of approximately $32 million for interest associated with the Company's 2028 senior notes.
PIL debt service payments include $40-$45 million of amortization payments as well as interest payments on the facility, reaching an estimated 2025 year-end balance range of $65-$70 million (and down from just over $100 million at year-end 2024).
Colombia and Ecuador Upstream Production and Operating Costs Guidance
In the Company's core Colombia and Ecuador Upstream business, Frontera plans to produce 41,000-43,000 boe/d while reducing capital investment by 13% to $200-$245 million compared to 2024.
The Company's 2025 average daily production guidance range does not include in-kind royalties, operational consumption, volumetric compensation or, potential production from successful exploration activities planned in 2024. The Company anticipates delivering between $350 to $380 million and $400 to $430 million in Operating EBITDA in 2025 from its Upstream operations at $75/bbl and $80/bbl average Brent prices, respectively.
The Company estimates 2025 production costs to remain flat compared to 2024 levels and to average $8.75 - $9.25 per boe, excluding energy costs reflecting the positive impact of implemented cost savings initiatives partially offset by incremental costs associated with additional water handling and treatment volumes (primarily associated to SAARA) and continued inflationary pressures.
Energy costs, which include electricity consumption and the costs of in-situ power generation, are expected to average $5.25 - $5.75 per boe, driven by higher energy use associated with increasing heavy crude oil production.
Transportation costs for 2025 are forecasted to average $12.50 - $13.00 per boe reflecting primarily increases in trucking tariffs resulting from changes to Colombian diesel subsidies starting in 2024 and stepping up in 2025 as well as inflation-related pipeline tariffs increases.
About Frontera's 2025 Upstream Spending
Frontera's anticipates its total 2025 Colombia and Ecuador Upstream capital expenditures will be $200-$245 million which represents an approximately 13% decrease at the midpoint compared to the Company's 2024 capital budget. 2025 Capital expenditures will support development and exploration activities as shown below.
Development Activities
Frontera anticipates spending approximately $100-$110 million to drill up to 62 wells (60 producer wells and 2 injector wells) in 2025 and approximately $60-$80 million on development facilities primarily supporting activities in CPE-6 and Quifa.
Colombia
Quifa block: Frontera plans to drill 26 wells (25 producer wells and 1 injector well) in the Quifa SW field and install additional production and injection facilities. At the Cajua field, Frontera plans to drill 15 producer wells and facilities for the field.
CPE-6 block: The Company plans to drill 20 wells (19 producer wells and 1 injector well) and install additional flow handling and injector line facilities.
Ecuador
Perico block (Frontera 50% W.I. and operator): The Company intends to drill the Perico Centro 3 well in 2025 (subject to regulatory and partner approval).
Other capital expenditures include plans to invest in regulatory and HSEQ activities and in field production technologies looking to enhance production efficiency and reduce water production.
Exploration:
In 2025, the Company anticipates investing $30-$40 million on various exploration activities including:
Drilling the high-impact Hidra-1 exploration well in the VIM-1 Block (Frontera 50% W.I., non-operator). The well is expected to spud during the first half of 2025.
Drilling the Greta Norte-1 well in the Cachicamo block in January 2025, a follow up to the Papilio-1 well.
Drilling the Llanera-1 well in the Llanos 99 block.
Carrying out pre-seismic and pre-drilling activities in the VIM-46 block in Colombia.
About Frontera's 2025 Colombian Infrastructure Spending
In the Company's Colombia infrastructure business, Frontera expects to generate between $20-$35 million in segment Operating EBITDA and between $115-$130 million in Adjusted Infrastructure EBITDA. The expected year over year increase is driven by additional EBITDA generated from the Reficar connection start up and additional revenues from SAARA. Frontera anticipates investing $15-$20 million primarily for:
Puerto Bahia: Commissioning and completion works related to the Reficar connection and maintenance activities for the port.
SAARA & Proagrollanos: Investments related to palm oil plantation biological asset maintenance, water handling infrastructure and the SAARA facility.
2025 Hedging Program
Frontera uses derivative commodity instruments to manage exposure to price volatility by hedging a portion of its oil production. The Company's strategy aims to protect 40-60% of its estimated net after royalties' production using a combination of instruments, capped and non-capped, to protect the revenue generation and cash position of the Company, while maximizing the upside, allowing the Company to take a more dynamic approach to the management of its hedging portfolio. The following table summarizes Frontera's 2025 hedging position as of December 10, 2024.
The Company is exposed to foreign currency fluctuations primarily arising from expenditures that are incurred in COP and its fluctuation against the USD. As of December 10, 2024, the Company had entered into new positions of foreign currency derivatives contracts as follows:
