UNITED STATES
SECURITIES AND
EXCHANGE COMMISSION
Washington, D.C.
20549
FORM 6-K
REPORT
OF FOREIGN PRIVATE ISSUER PURSUANT TO RULE 13a-16 OR 15d-16 UNDER THE SECURITIES EXCHANGE ACT OF 1934
For the month of
May 2024
Commission File
Number: 001-36298
GeoPark Limited
(Exact name of
registrant as specified in its charter)
Calle 94 N°
11-30 8° piso
Bogota, Colombia
(Address of principal
executive office)
Indicate by check
mark whether the registrant files or will file annual reports under cover of Form 20-F or Form 40-F:
GEOPARK LIMITED
TABLE OF CONTENTS
| ITEM |
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| 1. |
Press Release dated May 13, 2024 titled “GeoPark Announces Acquisition
of Working Interest in Four High Quality Adjacent Blocks in World Class Vaca Muerta” |
Item 1
| FOR IMMEDIATE DISTRIBUTION |
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GEOPARK ANNOUNCES ACQUISITION OF WORKING INTEREST
IN FOUR HIGH QUALITY ADJACENT BLOCKS IN WORLD CLASS VACA MUERTA
EXISTING PRODUCTION, RESERVES AND CASH FLOW
LOW-RISK DEVELOPMENT UNDERWAY WITH LARGE SCALE
UPSIDE
WELL-POSITIONED ACREAGE WITH AVAILABLE INFRASTRUCTURE
PROVEN UNCONVENTIONAL STRATEGIC PARTNER
Bogota, Colombia –
May 13, 2024 - GeoPark Limited (“GeoPark” or the “Company”) (NYSE: GPRK), a leading independent Latin American
oil and gas explorer, operator, and consolidator, today announced that it has signed an Asset Purchase Agreement with Phoenix Global Resources
(“PGR”), a subsidiary of Mercuria Energy Trading (“Mercuria”), for the acquisition of non-operated working interest
(WI) in four adjacent unconventional blocks in the Neuquén Basin in Argentina as follows: a 45% WI in each of the Mata Mora Norte
producing block and Mata Mora Sur exploration block, located in Neuquén Province, and a 50% WI in each of the Confluencia Norte
and Confluencia Sur exploration blocks, located in Rio Negro Province.
KEY HIGHLIGHTS
Robust Strategic Fit
| · | The
Vaca Muerta shale formation is the best onshore hydrocarbons play in Latin America today.
It holds an estimated 16 billion bbl of oil and 300+ Tcf of unconventional gas resources
with less than 10% developed to date1 |
| · | Oil
production from Vaca Muerta has grown almost 4x since 2019 to 352,715 bopd.2
It is currently
contributing 50% of Argentina’s total oil production, and has the potential to triple
again over the next six years |
| · | Vaca Muerta has been significantly de-risked since
2009, with the drilling of almost 7,000 exploration and development wells |
| · | The
blocks are located in the oil window of the Vaca Muerta formation in the Neuquen Basin, one
hour from Neuquen city and close to the services hub. Immediately adjacent blocks currently
produce over 28,000 gross boepd3 |
| · | GeoPark leverages more than 20 years of operational
and business presence in Argentina |
| · | Acquisition complements existing GeoPark portfolio
assets in Colombia, Ecuador and Brazil |
Immediate Access to
Rapidly Growing Production Profile
| · | The new assets would increase GeoPark’s
2024 production by an estimated 5,500-6,500 net boepd, subject to when the closing date of the transaction occurs |
| · | Average
gross production of the assets was 11,220 boepd in 1Q20244 and
12,594 boepd in March 20245 |
| · | Gross exit production for 2024 is expected to
be between 13,500-14,000 boepd |
| · | Approximately 150 more gross drilling locations
have been identified for the full development of the Mata Mora Norte Block |
| · | Under the agreed indicative development program,
production from the Mata Mora Norte Block is expected to reach approximately 40,000 gross boepd by 2028 |
1 Source:
US Energy Information Administration (EIA), World Shale Gas and Shale Oil Resource Assessment, 2013.
2 Source:
Sistema SESCO, Ministry of Energy, Argentina, average February 2024.
3 Average gross boepd in
January 2024.
4 Gross
average production January-February, 2024, according to government data and gross average March preliminary production data from PGR,
subject to variations and adjustments.
5 Gross average March preliminary
production data from PGR, subject to variations and adjustments.
Immediate Access to
Rapidly Growing Reserves Profile
| · | The transaction represents access to 25 mmboe
of 1P net reserves, 49.5 mmboe of 2P net reserves, and 102.6 mmboe of 3P net reserves, according to the Degolyer & MacNaughton (D&M)
certification from December 2023 |
| · | GeoPark’s 1P Reserve Life Index (RLI) would
grow to 6.7 years (from 5.4 years) and 2P Reserve Life Index (RLI) to 11.8 years (from 9.1 years) (D&M, December 2023) |
Value Accretive from
Day One
| · | The
Mata Mora Norte Block is expected to generate net Adjusted EBITDA of $90-100 million6
in full year
2024 with a 68% Adjusted EBITDA margin (at $80-90/bbl Brent oil price) |
| · | At expected plateau production of 40,000 gross
boepd in 2028-2030, the assets are expected to contribute $290-295 million of EBITDA to GeoPark (at $70/bbl Brent oil price) |
| · | Net
NPV10 of 1P Reserves is $364 million and net NPV10 of 2P reserves is $823 million7 |
Significant, Low-Risk
Exploration Upside
| · | The Mata Mora Sur, Confluencia Norte and Confluencia
Sur blocks are currently in the exploration phase and represent significant potential production and reserves upside |
| · | The three exploration blocks have 79,000 gross
acres and 241 mmboe of gross 3C certified Contingent resources (118 mmboe net to GeoPark) |
| · | Exploration acreage is estimated to add 200 gross
drilling locations |
| · | Production from the exploration assets could reach
15,000 – 20,000 gross boepd by 2028 on a P50 basis, subject to exploration success |
| · | First exploratory well on the Confluencia Norte
Block is underway |
Proven Partner &
Operator
| · | PGR is an independent exploration and production
(E&P) company focused on unconventional operations in Argentina. PGR is a subsidiary of Mercuria, one of the world’s leading
independent energy and commodity groups, with more than $174 billion of gross revenue and $6.7 billion of equity in 2022 |
| · | PGR has grown production at Mata Mora Norte from
zero to 13,000+ gross boepd in only three years, effectively de-risking 110 mmbbl of gross 2P reserves (D&M, December 2023) |
| · | With robust design, Drilling & Completion
(D&C) costs have fallen from $15.9 million per well in 2022 to $14.3 million per well in 2023, a highly competitive level compared
to the major Vaca Muerta producers |
| · | Lifting costs decreased from $8.10 per boe in
2022 to $5.80 per boe in 2023, and are expected to fall further to $5.10 per boe in 2024e (without transportation cost) |
| · | The partnership between GeoPark and PGR represents
an opportunity to jointly leverage the substantial operational, technical, financial and commercial expertise of both companies –
underpinned by unique complementary entrepreneurial culture - to unlock the full potential of the acquired blocks |
Summary of Terms
| · | GeoPark will pay $190 million for a total of 122,315
gross acres (58,402 net acres) |
| · | In addition to the upfront consideration, GeoPark
will fund 100% of exploratory commitments up to $113 million gross ($57 million of net carry), to be funded over two years, an acquisition
of midstream capacity according to the WI of $11 million, and a $10 million bonus contingent on results in the Confluencia exploration
campaign |
| · | The transaction is expected to close before the
end of 3Q2024, pending customary regulatory approvals |
6 Calculated
at Brent $80 – 90 per barrel. The Company is unable to present a quantitative reconciliation of the Adjusted EBITDA ratio which
is a forward-looking non-GAAP measure, because the Company cannot reliably predict certain of its necessary components, such as is the
case of Adjusted EBITDA, write-off of unsuccessful exploration efforts or impairment loss on non-financial assets, etc.
7
Calculated at price curve in the D&M PGR report from December 2023.
Competitive Valuation
Metrics
| · | For
Mata Mora Norte Block, the valuation is approximately $9,000 per acre8 |
| · | Based on net reserves, the valuations are $7.1/boe
1P reserves and $3.5/boe 2P reserves (D&M, December 2023) |
| · | Valuation per flowing barrel at closing is approximately
$28,000 |
| · | The 2024 EV/EBITDA multiple is 1.8x (at $80-90
Brent oil price) |
| · | The plateau EV/EBITDA multiple is 0.6x (at $70
Brent oil price) |
Financing and Capital
Structure
| · | The upfront consideration will be funded with
a mix of available cash and a partial draw of an existing oil prepayment facility that offers flexible and cost-effective terms. Longer
term commitments will be funded with a combination of cash generated by the assets and financing |
| · | The
pro forma net debt to Adjusted EBITDA ratio following the transaction is not expected to
exceed 1.1x9 |
Strategic Facilities
and Infrastructure
| · | Facilities are in place to handle 20,000 boepd
of gross production, and additional facilities will be in place by 2025-2026 to handle the expected plateau production |
| · | Two oil pipelines run directly through the block
and a third is under construction, facilitating transport options for exports |
| · | Approximately 90% of oil sales are transported
by pipeline, with 70% destined for export and 30% for the domestic market |
| · | Gas production is approximately 6% of total production,
with 50% sold to third parties and 50% used for internal consumption |
Indicative Activity
Plans
| · | The Mata Mora Norte Block currently has a dedicated
drilling rig that is scheduled to drill 12-15 wells in 2024 |
| · | The full development and exploration plan for
the Mata Mora Norte Block includes adding a second drilling rig in late 2025 to continue growing production to expected plateau levels,
which include risked estimates of seven committed wells on two exploration blocks |
Andrés Ocampo,
Chief Executive Officer of GeoPark, said: “This transaction is transformational for GeoPark, adding immediate value-accretive production
and reserves growth, while materially increasing and diversifying our long-term drilling inventory into one of the most prolific petroleum
systems in the world. We are particularly encouraged by achieving this strategic step change alongside PGR, a proven and established operator
with world class shareholders and great success in efficiently developing and de-risking the unconventional opportunities in Vaca Muerta.”
8 Net
acres, 19,459.
9 Considers full year 2024
of new assets.
KEY
METRICS AND MAP
| |
Mata Mora
Norte |
Mata Mora
Sur |
Confluencia
Norte |
Confluencia
Sur |
| Gross Acres |
43,243 |
11,861 |
25,698 |
41,513 |
| GeoPark WI |
45% |
45% |
50% |
50% |
|
Current Production
Gross boepd |
11,207
|
- |
- |
- |
| Gross 1P Reserves (D&M) |
55 mmboe |
- |
- |
- |
| Gross 2P Reserves (D&M) |
110 mmboe |
- |
- |
- |
| Net 2P NPV10 |
$823 mm |
|
|
|
|
Unconventional
License and Permit Types |
Exploitation License |
Exploration Permit |
Exploration Permit |
Exploration Permit |
| License Expiration Date |
2056 |
2026 |
2026 |
2026 |
| Certified 3C Contingent Resources (mmboe) |
|
51 |
78 |
112 |
| Well Stock |
140-160 |
15-20 |
137-200 |
| Province |
Neuquen |
Neuquen |
Rio Negro |
Rio Negro |
|
For further information, please
contact:
INVESTORS:
Stacy Steimel ssteimel@geo-park.com
Shareholder Value Director
T: +562 2242 9600
Miguel Bello mbello@geo-park.com
Market Access Director
T: +562 2242 9600
Diego Gully dgully@geo-park.com
Capital Markets Director
T: +55 21 99636 9658 |
|
MEDIA:
| Communications Department |
communications@geo-park.com |
GLOSSARY
| 1P |
Proven Reserves |
| 2P |
Proven plus Probable Reserves |
| 3P |
Proven plus Probable plus Possible Reserves |
| Adjusted EBITDA |
Adjusted EBITDA is defined as profit for the period before net finance costs, income tax, depreciation, amortization, the effect of IFRS 16, certain non-cash items such as impairments and write-offs of unsuccessful efforts, accrual of share-based payments, unrealized results on commodity risk management contracts and other non-recurring events |
| boe |
Barrels of oil equivalent (6,000 cf marketable gas per bbl of oil equivalent). Marketable gas is defined as the total gas produced from the reservoir after reduction for shrinkage resulting from field separation; processing, including removal of nonhydrocarbon gas to meet pipeline specifications; and flare and other losses but not from fuel usage |
| boepd |
Barrels of oil equivalent per day |
| bopd |
Barrels of oil per day |
| Certified Reserves |
Refers to GeoPark working interest reserves before royalties paid in kind, independently evaluated by the petroleum consulting firm, DeGolyer and MacNaughton Corp. (D&M) |
| mboed |
Thousands of barrels of oil equivalent per day |
| mmboe |
Millions of barrels of oil equivalent |
| NPV10 After Tax |
Net Present Value after tax discounted at 10% rate |
| PD |
Proven Developed Reserves |
| PRMS |
Petroleum Resources Management System |
| RLI |
Reserve Life Index |
| WI |
Working Interest |
NOTICE
Additional information
about GeoPark can be found in the Invest with Us section of the website at www.geo-park.com
The reserve estimates provided in this release
are estimates only, and there is no guarantee that the estimated reserves will be recovered. Actual reserves may eventually prove to be
greater than, or less than, the estimates provided herein. Statements relating to reserves are by their nature forward-looking statements.
Gas quantities estimated
herein are reserves to be produced from the reservoirs, available to be delivered to the gas pipeline after field separation prior to
compression. Gas reserves estimated herein include fuel gas.
Rounding amounts and percentages:
Certain amounts and percentages included in this press release have been rounded for ease of presentation. Percentage figures included
in this press release have not in all cases been calculated on the basis of such rounded figures, but on the basis of such amounts prior
to rounding. For this reason, certain percentage amounts in this press release may vary from those obtained by performing the same calculations
using the figures in the financial statements. In addition, certain other amounts that appear in this press release may not sum due to
rounding.
Oil and gas production
figures included in this release are stated before the effect of royalties paid in kind, consumption and losses.
All evaluations of future
net revenue contained in the D&M Reports are after the deduction of cash royalties, development costs, operating expenses, production
and profit taxes, fees, earn out payments, well abandonment costs, and country income taxes from the future gross revenue. It should not
be assumed that the estimates of future net revenues presented in the tables represent the fair market value of the reserves. The actual
production, revenues, taxes and development, and operating expenditures with respect to the reserves associated with the Company's properties
may vary from the information presented herein, and such variations could be material. In addition, there is no assurance that the forecast
price and cost assumptions contained in the D&M Report will be attained, and variances could be material.
CAUTIONARY
STATEMENTS RELEVANT TO FORWARD-LOOKING INFORMATION
This press release contains
statements that constitute forward-looking statements. Many of the forward-looking statements contained in this press release can be identified
by the use of forward-looking words such as ‘‘anticipate,’’ ‘‘believe’’, ‘‘could,’’
‘‘expect,’’ ‘‘should,’’ ‘‘plan,’’ ‘‘intend,’’
‘‘will,’’ ‘‘estimate’’ and ‘‘potential,’’ among others.
Forward-looking statements that appear in a number
of places in this press release include, but are not limited to, statements regarding the intent, belief or current expectations, regarding
various matters including production growth, development programs, Reserve Life Index, Adjusted EBITDA, net EBITDA, lifting costs and
pro forma net debt to Adjusted EBITDA. Forward-looking statements are based on management’s beliefs and assumptions, and on information
currently available to the management. Such statements are subject to risks and uncertainties, and actual results may differ materially
from those expressed or implied in the forward-looking statements due to various factors.
Forward-looking statements
speak only as of the date they are made, and the Company does not undertake any obligation to update them in light of new information
or future developments or to release publicly any revisions to these statements in order to reflect later events or circumstances or to
reflect the occurrence of unanticipated events. For a discussion of the risks facing the Company which could affect whether these forward-looking
statements are realized, see the Company’s filings with the U.S. Securities and Exchange Commission (SEC).
This press release
contains a number of oil and gas metrics, including NPV after tax per share, reserve life index, net debt-adjusted NPV per share,
etc., which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable
to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to
provide readers with additional measures to evaluate the Company's performance; however, such measures are not reliable indicators
of the future performance of the Company and future performance may not compare to the performance in previous periods.
Information about oil
and gas reserves: The SEC permits oil and gas companies, in their filings with the SEC, to disclose only proven, probable and possible
reserves that meet SEC definitions for such terms. GeoPark uses certain terms in this press release, such as "PRMS Reserves"
that SEC guidelines do not permit GeoPark from including in filings with the SEC. As a result, the information in the Company’s
SEC filings with respect to reserves will differ significantly from the information in this press release. NPV10 after tax for PRMS 1P,
2P and 3P reserves is not a substitute for the standardized measure of discounted future net cash flows for SEC proved reserves.
SIGNATURE
Pursuant to the
requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned,
thereunto duly authorized.
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GeoPark Limited |
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By: |
/s/ Jaime Caballero Uribe |
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Name: |
Jaime Caballero Uribe |
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Title: |
Chief Financial Officer |
Date:
May 13, 2024
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