GeoPark Announces Fourth Quarter 2018 Operational Update

Record Annual Oil and Gas Production up 31%

Extending Consistent 15-Year Growth Track Record

More Than 85% Drill Bit Success

Acquisition of Key Colombian Llanos 34 Interests

BOGOTA, Colombia--()--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, Peru, Argentina, Brazil and Chile, today announced its operational update for the three-month period ended December 31, 2018 (“4Q2018”).

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

Fourth Quarter 2018 Highlights

Oil and Gas Production: Hits and Exceeds Targets

  • Annual 2018 average production up 31% to 36,027 boepd, hitting 35,500-36,500 boepd guidance
  • Record 2018 exit production of 39,600 boepd, exceeded guidance of 38,000-39,000 boepd
  • Consolidated oil and gas production up 26% to 38,741 boepd (up 4% compared to 3Q2018)
  • Oil production increased by 30% to 32,859 bopd (up 5% compared to 3Q2018)
  • Gross operated production in Llanos 34 block (GeoPark operated, 45% WI) surpassed 70,000 bopd
  • Gas production increased by 11% to 35.3 mmcfpd

Operations: Capital Efficiency and Execution

  • GeoPark’s 2018 work program included a total of 33 gross wells drilled (30 operated with a success rate of over 85%), including development, appraisal and exploration wells, as part of its $140-150 million capital expenditure plan
  • In Colombia: eight new wells were tested and put on production in the Llanos 34 block, adding 7,000 bopd gross from new wells. Llanos 34 flowline on schedule and on budget
  • In Brazil: Praia dos Castelhanos 1 exploration well was drilled in the REC- T-128 block (GeoPark operated, 70% WI) and will be completed and tested in 1Q2019

Portfolio Growth: Acquisition of LGI’s Interests in Colombia and Chile

  • Acquired LGI’s 20% equity interest in GeoPark’s Chilean and Colombian subsidiaries, which expanded the Company’s participation in the valuable Llanos 34 block, and contributed with significant corporate synergies and bottom-line benefits
  • Divested high-cost, non-core La Cuerva and Yamu Colombian assets for up to $20 million

Catalysts: 1Q2019

  • Testing five drilled wells and drilling five new wells, including development, appraisal and exploration wells across the pan-regional portfolio in Colombia, Argentina, Brazil and Chile
  • Flowline in the Llanos 34 block expected to be operational in 1Q2019
  • New independent reserves certification by DeGolyer and MacNaughton (D&M) underway and expected to be released in early February 2019

Breakdown of Quarterly Production by Country

The following table shows production figures for 4Q2018, as compared to 4Q2017:

      4Q2018       4Q2017







      % Chg.
Colombia 30,641       30,497       863 24,378       +26%
Brazil 2,894 41 17,117 3,328 -13%
Chile 2,823 725 12,585 2,932 -4%
Argentina       2,383       1,596       4,723       16       -
Total       38,741       32,859       35,288       30,654       +26%

a) Includes royalties paid in kind in Colombia for approximately 1,181 bopd in 4Q2018. No royalties were paid in kind in Brazil, Chile or Argentina.

Quarterly Production Evolution

(boepd)       4Q2017       1Q2018       2Q2018       3Q2018       4Q2018
Colombia       24,378       26,405       27,940       29,139       30,641
Brazil 3,328 2,775 2,904 3,124 2,894
Chile 2,932 2,873 2,559 2,632 2,823
Argentina       16       142       2,467       2,319       2,383
Total       30,654       32,195       35,870       37,214       38,741
Oil 25,341 27,345 30,249 31,266 32,859
Gas 5,313 4,850 5,621 5,948 5,882

Oil and Gas Production Update


Overall oil and gas production grew by 26% to 38,741 boepd in 4Q2018 from 30,654 boepd in 4Q2017, due to increased production in Colombia and new production from the recent Argentina acquisitions.

Oil represented 85% of total reported production compared to 83% in 4Q2017.


Average net production in Colombia grew 26% to 30,641 boepd in 4Q2018 compared to 24,378 boepd in 4Q2017, reflecting continued successful appraisal and development drilling in Tigana and Jacana oil fields in the Llanos 34 block, which represented 96% of Colombian production in 4Q2018.

By end-December 2018, the Llanos 34 block surpassed the 70,000 gross bopd milestone, extending seven years of production growth and operating momentum, and setting a solid base for continued growth during 2019.

Llanos 34 block 4Q2018 operational results:

Exploration drilling:

  • Tigui Sur 1 well, located south of the Tigui 1 exploration well, next to the southern border of the Llanos 34 block, was successfully tested during 4Q2018. Tigui oil field (including Tigui 1 and Tigui Sur 1 wells) is currently producing 1,900 bopd with a 6% water cut.
  • The Company is currently drilling Tigui 2 appraisal well, located 870 meters east of Tigui 1 well, to continue delineating the size and distribution of the reservoir.

Development and appraisal drilling:

  • Seven new wells were tested and put on production, including Tigana 5, Tigana Norte 10, Tigana Norte 11, Tigana Norte 12, Tua 11, Jacana 14 and Jacana 19, which are currently producing approximately 6,800 bopd gross.

Infrastructure update:

  • The flowline to connect the Llanos 34 block to the Oleoducto de los Llanos (ODL), one of Colombia’s principal pipelines (with a capacity of 314,000 bopd) is on budget and on schedule and is expected to be operational in 1Q2019. The project will support future production growth (with a capacity of up to 100,000 bopd) and reduce transportation and operating costs.

Sale of La Cuerva and Yamu non-core assets:

  • In November 2018, GeoPark signed an agreement with Perenco Oil and Gas to divest the La Cuerva and Yamu blocks for $18 million plus a contingent payment of $2 million based on future oil prices. GeoPark will continue operating the La Cuerva and Yamu blocks until the closing of this transaction, expected in 1Q2019.

For a summary of upcoming drilling and testing activities, please refer to the 1Q2019 drilling schedule below.


During 4Q2018, GeoPark successfully concluded the last round of workshops with local communities. The Company is currently waiting for additional comments from Servicio Nacional de Certificación Ambiental para las Inversiones Sostenibles, which is the last step of the Environmental Impact Assessment approval process.

The Morona block (GeoPark operated, 75% WI) contains the Situche Central oil field, which has been delineated by two wells that tested combined production rates of 7,500 bopd of light oil with identified upside potential of more than 200 mmbo. As of December 2017, D&M certified gross proven and probable (2P) reserves of 42.1 mmbo and 3P reserves of 83.0 mmbo for the Situche Central oil field.


Average net production in Argentina totaled 2,383 boepd in 4Q2018 (67% oil, 33% gas) corresponding to the acquisition of the Aguada Baguales, El Porvenir and Puesto Touquet blocks (GeoPark operated, 100% WI) in the Neuquen basin. Net production levels in 4Q2018 increased by 3% compared to 3Q2018, due to an ongoing secondary recovery optimization project that included a low-cost well intervention campaign initiated in August 2018.

Testing activities in the El Porvenir block (GeoPark operated, 100% WI):

  • Site preparation and installation activities completed during 4Q2018 to test a tight gas play in the Challaco Bajo 1001 well. Testing expected to begin in January 2019.

Exploration drilling in the CN-V block (GeoPark, 50% WI):

  • Initial testing activities in the Rio Grande Este 1 exploration well were unsuccessful. The joint venture is currently evaluating subsequent steps.

For a summary of upcoming drilling and testing activities, please refer to the 1Q2019 drilling schedule below.


Average net production in the Manati field (GeoPark non-operated, 10% WI) decreased by 13% to 2,894 boepd in 4Q2018, compared to 3,328 boepd in 4Q2017, due to lower gas demand for power generation as a result of increased hydroelectric power availability.

Exploration drilling in the REC-T-128 block:

  • Praia dos Castelhanos 1 exploration well was drilled to a total depth of 8,431 feet. Testing activities expected during 1Q2019.


Average net oil and gas production in Chile decreased by 4% to 2,823 boepd in 4Q2018 compared to 2,932 boepd in 4Q2017, but increased 7% compared to 3Q2018 due to the recent discovery of the Jauke gas field. The production mix during 4Q2018 was (74% gas, 26% light oil vs. 66% gas, 34% light oil in 4Q2017). The Fell block (GeoPark operated, 100% WI) represented 100% of Chilean production in 4Q2018.

During 4Q2018, surface facilities optimization resulted in an increase of overall gas production levels. The Fell block is currently producing 3,000-3,100 boepd (80% gas, 20% light oil).

For a summary of upcoming drilling and testing activities, please refer to the 1Q2019 drilling schedule below.

1Q2019 Drilling Schedule

The following is a summary of expected drilling and testing activities scheduled for 1Q2019:

    Prospect/Wella       Country       Block       WI       Type
1   Tigana Sur Oeste 10       Colombia       Llanos 34       45%       Development

Aruco 2b

Colombia Llanos 34 45% Development

Tigui 2b

Colombia Llanos 34 45% Appraisal
4 Tua 13 Colombia Llanos 34 45% Development

Jacana 23b

Colombia Llanos 34 45% Development
6 Jacana 31 Colombia Llanos 34 45% Development

Challaco Bajo -1001c

Argentina El Porvenir 100% Exploration
8 Challaco Bajo -2002 Argentina El Porvenir 100% Development

Praia dos Castelhanos 1b

Brazil REC-T-128 70% Exploration
10 Jauke 2 Chile Fell 100% Development

a) Information included in the table above is subject to change and may also be subject to partner or regulatory approval

b) Drilling initiated or completed with testing activities expected in 1Q2019

c) Drilled in prior years by the previous operator of the block before GeoPark acquired the assets. Testing activities expected in 1Q2019



Adjusted EBITDA Adjusted EBITDA is defined as profit for the period before net finance costs, income tax, depreciation, amortization, 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
Adjusted EBITDA per boe Adjusted EBITDA divided by total boe deliveries
Operating netback per boe Revenue, less production and operating costs (net of depreciation charges and accrual of stock options and stock awards) and selling expenses, divided by total boe deliveries. 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
CEOP Contrato Especial de Operacion Petrolera (Special Petroleum Operations Contract)
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



Last Twelve Months

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
Mm3/day Thousand cubic meters per day
PRMS Petroleum Resources Management System
SPE Society of Petroleum Engineers
WI Working interest
NPV10 Present value of estimated future oil and gas revenues, net of estimated direct expenses, discounted at an annual rate of 10%
Sqkm Square kilometers


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 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.


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 expected production growth, expected schedule, economic recovery, payback timing, IRR, drilling activities, demand for oil and gas, 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 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 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.


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

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

Jared Levy – Sard Verbinnen & Co
New York, USA
T: +1 (212) 687-8080

Kelsey Markovich – Sard Verbinnen & Co
New York, USA
T: +1 (212) 687-8080


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

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

Jared Levy – Sard Verbinnen & Co
New York, USA
T: +1 (212) 687-8080

Kelsey Markovich – Sard Verbinnen & Co
New York, USA
T: +1 (212) 687-8080