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GeoPark Announces Second Quarter 2021 Operational Update

BOGOTA, Colombia, July 22, 2021 (BUSINESS WIRE) --

GeoPark Limited ("GeoPark" or the "Company") (NYSE: GPRK), a leading independent Latin American oil and gas explorer, operator and consolidator with operations and growth platforms in Colombia, Ecuador, Chile, Brazil, and Argentina, today announced its operational update for the three-month period ended June 30, 2021 ("2Q2021").

All figures are expressed in US Dollars. Growth comparisons refer to the same period of the prior year, except when otherwise specified.


Oil and Gas Production and Operations

Consolidated oil and gas production of 36,489 boepd, impacted by managed curtailments due to extensive protests and demonstrations that affected overall logistics throughout Colombia(1) Production restored by the end of 2Q2021, with GeoPark currently producing 38,000-39,000 boepd Drilling and field operations normalized by the end of 2Q2021 and currently fully active with three operated drilling rigs and three workover rigs in Colombia

Ongoing Operations and Revised 2021 Guidance

Full-year 2021 average production has been revised to 38,000-40,000 boepd with a work program of $125-140 million and operating netbacks of $340-390 million (assuming Brent at $60-65 per bbl)(2) 2H2021 production is expected to average 39,000-42,000 boepd (excluding the potential production from the 2H2021 exploration drilling program) 2H2021 drilling program includes exploration prospects in the CPO-5 (GeoPark non-operated, 30% WI) and Llanos 94 (GeoPark non-operated, 50% WI) blocks Flexible work program, quickly adaptable to any oil price scenario

Debt Reduction and Cost Savings

Strategic first phase deleveraging process executed in April 2021, resulting in significant debt reduction with extended maturities and lower cost of debt $85 million of cash & cash equivalents as of June 30, 2021(3) Long-term financial debt maturity profile with no principal payments until September 2024

ESG+ Actions

National electric grid connection and PV solar projects currently underway to continue improving industry-leading cost and carbon footprint performance in the Llanos 34 block (GeoPark operated, 45% WI) Currently developing strategic medium and long-term greenhouse gas reduction policy GeoPark's annual sustainability report (SPEED/ESG 2020 report) to be published in August 2021

Corporate Governance Strengthening

Shareholders reelected all GeoPark directors at the AGM(4) held on July 15, 2021, with every director receiving at least 70% of the shares voted Newly appointed Independent Chair of the Board, Ms. Sylvia Escovar GeoPark's Board composed of a majority of independent directors and key committees consist solely of independent directors (Nomination and Corporate Governance, Audit, and Compensation committees)

Returning Cash and Value to Shareholders

Quarterly Dividend of $0.0205 per share ($1.25 million), paid on April 13, 2021 Quarterly Dividend of $0.0205 per share ($1.25 million), paid on May 28, 2021 Resumed discretionary share buyback program, having acquired 241,927 shares for $2.9 million since November 6, 2020, while executing self-funded and flexible work programs, and paying down debt

Ongoing Portfolio Restructuring

Peru: Executed agreement to transfer the Morona block contract and operatorship to Petroperu Brazil: Manati gas field divestment process expected to close by the end of 2021 Brazil: REC-T-128 block farm-out closed during May 2021 Argentina: initiated a process during May 2021 to evaluate farm-out/divestment opportunities Asset management restructuring initiative providing G&A, OPEX and other cost improvements


As announced on May 17, June 1 and July 1, extensive protests and demonstrations across Colombia affected overall logistics and supply chains, restricting GeoPark's crude oil transportation, drilling and the mobilization of personnel, equipment, and supplies. These events caused the Company and its joint venture partners to manage production curtailments and to temporarily suspend or delay drilling and maintenance activities.

Operations normalized by the end of 2Q2021 and GeoPark is currently producing 38,000-39,000 boepd, with 2H2021 production expected to average 39,000-42,000 boepd.

Revised 2021 production guidance of 38,000-40,000 average boepd (from previous 41,000-43,000 boepd) results from production curtailments during 2Q2021 related to extensive protests in Colombia (which account for approximately 800-1,000 boepd of the revised estimate), delays in the execution of certain maintenance and capital expenditure projects (mainly in the Platanillo and CPO-5 blocks) and to a lesser extent, due to a combination of field and well performance, including higher downtime due to floods temporarily affecting surface facilities and electrical system failures in the Llanos 34 block.

Delayed maintenance and drilling activities in the Platanillo block were mainly caused by the blockades in Colombia. In the CPO-5 block, the operator has delayed the spud of the Indico 4 development well to 4Q2021 (originally scheduled for June 2021), targeting drilling of 2-3 wells during 2021 (from previous 5-6 wells, with the remaining 2-3 wells expected to be spudded in 1Q2022).

Capital expenditures have been revised down to $125-140 million (from $130-150 million), which will compensate a significant portion of the lower operating netbacks that results from lower production and thus reducing its impact on free cash flow.

The table below provides further details about GeoPark's revised 2021 guidance compared to its previous guidance.

                     July 22, 2021           Previous
                                                                                                   Revision                                                                       Guidance
------------------------------- -------------------- -------------------- -------------------- --------------- -------------------- -------------------- -------------------- ---------------
  Brent Assumption ($ per bbl)            $60-65(5)              $50-55
 2021 Average Production (boepd)        38,000-40,000         41,000-43,000
    2021 Operating Netback(6)          340-390 million       330-370 million
    2021 Capital Expenditures          125-140 million       130-150 million

Breakdown of Quarterly Production by Country

The following table shows production figures for 2Q2021, as compared to 2Q2020:

  2Q2021           2Q2021                2Q2020            2Q2020
   Total    Total    Oil     Gas          Total          Total % Chg.
  (boepd)  (boepd) (bopd)a (mcfpd)       (boepd)        (boepd)
--------- ------- ------- ------- -------------------- ------- ------
Colombia   29,571  29,333   1,428    31,072   -5%
Chile       2,584     284  13,800     3,101  -17%
Brazil      2,080      29  12,306       679  206%
Argentina   2,254   1,316   5,628     2,060   9%
--------- ------- ------- ------- -------------------- ------- ------
Total      36,489  30,962  33,162    36,912   -1%
--------- ------- ------- ------- -------------------- ------- ------

Quarterly Production Evolution

(boepd)   2Q2021 1Q2021 4Q2020 3Q2020 2Q2020
--------- ------ ------ ------ ------ ------
Colombia  29,571 31,455 31,858 31,297 31,072
Chile      2,584  2,491  3,133  3,610  3,101
Brazil     2,080  1,984  2,167  1,581    679
Argentina  2,254  2,201  2,146  2,357  2,060
--------- ------ ------ ------ ------ ------
Total     36,489 38,131 39,304 38,845 36,912
--------- ------ ------ ------ ------ ------
Oil       30,962 32,877 33,238 32,875 32,504

Oil and Gas Production Update


Oil and gas production in 2Q2021 decreased by 1% to 36,489 boepd from 36,912 boepd in 2Q2020, mainly resulting from lower oil and gas production in Colombia and Chile, partially offset by increased production in Brazil and Argentina.

Oil represented 85% and 88% of total reported production in 2Q2021 and 2Q2020, respectively.


Average net oil and gas production in Colombia decreased by 5% to 29,571 boepd in 2Q2021 compared to 31,072 boepd in 2Q2020.

GeoPark's 2Q2021 production in Colombia was affected by extensive protests and demonstrations that affected overall logistics, restricting the Company's crude oil transportation, drilling and the mobilization of personnel, equipment, and supplies, causing the Company to manage production curtailments that started in early May and normalized towards the end of June.

Oil and gas production in main blocks in Colombia was as follows:

Llanos 34 block net average production was 24,515 bopd in 2Q2021 and current production is approximately 25,000 bopd (or 56,000 bopd gross) CPO-5 block net average production was 3,445 bopd (or 11,483 bopd gross) in 2Q2021 and current production is approximately 3,900 bopd (or 13,000 bopd gross) Platanillo block average production was 1,110 bopd in 2Q2021 and current production is approximately 2,000 bopd

Latest developments in the Llanos 34 block:

Three active drilling rigs expecting to spud 14-16 gross wells during 2H2021 (mainly targeting development projects in Tigana, Jacana and Tigui oil fields) Environmental impact studies and other preliminary works underway to connect the block to the national power grid, expected to be operational by the end of 2022 Initiated engineering works for the PV solar project, expected to be operational by June 2022 Grid connection and PV solar projects are key drivers to continue improving the Llanos 34 block's industry-leading cost and carbon footprint performance

Latest developments in the CPO-5 block:

Completed 250 sq km of 3D seismic acquisition in 2Q2021, expected to add additional leads and prospects in the central area of the block

Other activities in operated and non-operated blocks:

Llanos 94 block (GeoPark non-operated, 50% WI): pre-drilling activities underway in the Humea exploration prospect, spudding expected in 3Q2021 PUT-8 block (GeoPark operated, 50% WI): Completed 112 sq km of 3D seismic acquisition in 2Q2021. PUT-8 is adjacent to the Platanillo block in the Putumayo basin


Average net production in Chile decreased by 17% to 2,584 boepd in 2Q2021 compared to 3,101 boepd in 2Q2020, resulting from lower gas production in the Jauke and Jauke Oeste gas fields. Maintenance and well intervention activities were carried out in Jauke Oeste, affecting gas production in 2Q2021. The production mix during 2Q2021 was 89% gas and 11% light oil (compared to 92% gas and 8% light oil in 2Q2020).


Average net production in Brazil increased by 206% to 2,080 boepd in 2Q2021 compared to 679 boepd in 2Q2020 due to higher gas demand in northern Brazil. The production mix during 2Q2021 was 99% natural gas and 1% oil and condensate (compared to 88% natural gas and 12% oil and condensate in 2Q2020).


Average net production in Argentina increased by 9% to 2,254 boepd in 2Q2021 compared to 2,060 boepd in 2Q2020. The production mix during 2Q2021 was 58% oil and 42% natural gas (compared to 61% oil and 39% natural gas in 2Q2020).


Reporting Date for 2Q2021 Results Release, Conference Call and Webcast

GeoPark will report its 2Q2021 financial results on Wednesday, August 4, 2021 after the market close.

In conjunction with the 2Q2021 results press release, GeoPark management will host a conference call on August 5, 2021 at 10:00 am (Eastern Daylight Time) to discuss the 2Q2021 financial results. To listen to the call, participants can access the webcast located in the Investor Support section of the Company's website at, or by clicking below:

Interested parties may participate in the conference call by dialing the numbers provided below:

United States Participants: 1 844-200-6205 International Participants: +44 208-0682-558 Passcode: 931620

Please allow extra time prior to the call to visit the website and download any streaming media software that might be required to listen to the webcast.

An archive of the webcast replay will be made available in the Investor Support section of the Company's website at after the conclusion of the live call.


AGM                    Annual General Meeting
ANP                    Brazil's National Agency of Petroleum, Natural Gas and Biofuels
Operating netback      Revenue, less production, and operating costs (net of accrual of stock options and stock awards), selling expenses and realized portion of commodity risk management contracts. Operating netback is equivalent to Adjusted EBITDA net of cash expenses included in Administrative, Geological and Geophysical and Other operating costs
Bbl                    Barrel
Boe                    Barrels of oil equivalent
Boepd                  Barrels of oil equivalent per day
Bopd                   Barrels of oil per day
D&M                    DeGolyer and MacNaughton
F&D costs              Finding and development costs, calculated as capital expenditures divided by the applicable net reserves additions before changes in Future Development Capital
Km                     Kilometers
Mboe                   Thousand barrels of oil equivalent
Mmbo                   Million barrels of oil
Mmboe                  Million barrels of oil equivalent
Mcfpd                  Thousand cubic feet per day
Mmcfpd                 Million cubic feet per day
Mm(3)/day              Thousand cubic meters per day
NPV10                  Present value of estimated future oil and gas revenues, net of estimated direct expenses, discounted at an annual rate of 10%
PRMS                   Petroleum Resources Management System
Sq km                  Square Kilometer
WI                     Working Interest


Additional information about GeoPark can be found in the "Investor Support" section on the website at

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 based on such rounded figures but based on 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.


This press release contains statements that constitute forward-looking statements. Many of the forward- looking statements contained in this press release can be identified using 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 the divestment process of the Manati gas field, engineering works for the PV solar project, the connection of the Llanos 34 block to the national electric power grid, expected production growth, expected schedule, economic recovery, payback timing, IRR, drilling activities, demand for oil and gas, oil and gas prices, capital expenditures plan, regulatory approvals, reserves and exploration resources. 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. Oil and gas production figures included in this release are stated before the effect of royalties paid in kind, consumption, and losses, except when specified.

Forward-looking statements speak only as of the date they are made, and the Company does not undertake any obligation to update them considering new information or future developments or to release publicly any revisions to these statements 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 filings with the U.S. Securities and Exchange Commission.

Readers are cautioned that the exploration resources disclosed in this press release are not necessarily indicative of long-term performance or of ultimate recovery. Unrisked prospective resources are not risked for change of development or chance of discovery. If a discovery is made, there is no certainty that it will be developed or, if it is developed, there is no certainty as to the timing of such development. There is no certainty that any portion of the prospective resources will be discovered. If discovered, there is no certainty that it will be commercially viable to produce any portion of the resources. Prospective resource volumes are presented as unrisked.

_________________________________ (1) Please refer to the Company's releases on May 17, June 1, and July 1, 2021. (2) Brent price assumption from July to December 2021, assuming $3-4/bbl Vasconia-Brent differential. (3) Unaudited. (4) Annual General Meeting. (5) Brent assumption from July to December 2021. (6) Assuming a Brent to Vasconia differential averaging $3-4 per bbl in 2H2021. (7) Ratio calculated using the middle point of operating netback and capital expenditures.

View source version on

SOURCE: GeoPark Limited

<img alt="" src="" style="width:0;height:0" />

Stacy Steimel, 
Shareholder Value Director
T: +562 2242 9600

Miguel Bello, 
Market Access Director
T: +562 2242 9600

Diego Gully, 
Investor Relations Director
T: +5411 4312 9400

Communications Department,
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