(Frontera Energy, 10.Oct.2018) — Frontera Energy Corporation announced a light oil discovery from its Acorazado-1 exploration well on the 100% owned and operated Llanos-25 block in Colombia. Frontera also provided an operational update highlighting current production, major project activities and details regarding the fourth quarter drilling campaign.
Richard Herbert, Chief Executive Officer of Frontera, commented:
“The Acorazado-1 exploration well is the fourth exploration discovery in Colombia so far in 2018, adding to the discoveries at Alligator and Coralillo on the Guatiquia block, and Jaspe in the Quifa area. This maintains our 100% track record of discoveries in Colombia in 2018.
The Acorazado-1 well encountered a number of potential hydrocarbon zones in the target Mirador Formation reservoir and two drill-stem tests were conducted. As a result, I am pleased that we have made a light oil discovery in our first deep well in the Llanos foothills trend. Data collected during testing show the Acorazado reservoir pressure to be lower than that expected in an undrained reservoir, indicating a probable hydraulic connection with the adjacent Cusiana structure to the north. While the lowered reservoir pressure impacts potential flow rates, the well has identified a part of the structure which contains resources which have never been previously drilled and developed. We plan to put the Acorazado-1 well on long-term test in the near future.
Operationally, current production has returned to planned levels above 65,000 boe/d, with Block 192 production in Peru averaging over 10,000 bbl/d since the block was restarted in September. We expect to add to production during the fourth quarter as the water handling expansion project at Quifa SW is brought on-stream. Frontera’s strong production profile is well-timed with the upcoming expiration of our oil hedges at the end of October which will increase our exposure to Brent oil prices by nearly $25 per barrel based on recent prices.
Additionally, we will be drilling some exciting exploration and appraisal wells during the fourth quarter including Coralillo-3 and Cocodrilo-1 on the Guatiquia block and additional Jaspe appraisal wells in the Quifa North area. Frontera will be presenting its 2019 operating plan and guidance in the second week of December, targeting production growth for the first time since restructuring in late 2016.”
Exploration Discovery in Colombia
The Acorazado-1 exploration well was drilled to a total measured depth of 15,470 feet (15,197 feet true vertical depth) and encountered 356 feet of gross thickness in the Mirador formation sandstone reservoir. Open-hole wireline logging operations identified five separate, potentially hydrocarbon-bearing sections of the Mirador formation (Mirador I, II, III, IV and VI) with an estimated total net thickness of 82 feet. A drill-stem test (DST) program with a tubing conveyed perforating system (TCP) was designed to evaluate the potential hydrocarbon bearing sections in two separate tests, the first testing the Mirador VI section and the second testing the Mirador I, II, III and IV sections, commingled.
The Mirador VI reservoir, was tested from 20 feet of perforations, using a DST-TCP tool with an average 2,360 psi drawdown for 52 hours during the main flow test prior to a pressure buildup test at an average rate of 455 barrels of fluids per day at natural flow. The average oil rate was 427 bbl/d of 36.9-degree API crude with an average natural gas rate of 896 mcf/d during the test. In total there were 1,003 bbls of oil and 2.1 Mmcf of natural gas produced during the Mirador-VI main flow test period, with oil gravity varying from 35.2 to 37.6-degree API. The maximum average flow rate over a 24-hour period at a choke size of 36/64th of an inch was 606 barrels of fluid per day, with a maximum average rate of 570 barrels of oil per day and average gas rate of 1.06 Mmcf/d.
The main flow test period was followed by a pressure buildup test which ended with a short flow period at restricted flow rates to collect bottomhole and separator fluid samples for lab analyses. The Company will now proceed with completing the Mirador VI reservoir in the coming months and is in the process of applying to the Agencia Nacional de Hidrocarburos (ANH) for a long-term testing license which will allow the Company to produce the well for six months with the potential for a further six-month extension while production facilities are placed at the well site.
The Mirador I to IV commingled reservoir was tested from 79 feet of total perforations, using a DST-TCP tool with an average 940 psi drawdown for 16 hours at an average rate of 370 barrels of fluids per day with a small volume of oil and natural gas.
Based on an evaluation of the results from both tests the Company believes that the intervals tested may have incurred formation damage from drilling and production testing operations which has limited the flow potential of the reservoir. Therefore, the Company will conduct an evaluation to identify potential methods to stimulate the Mirador I to IV and Mirador VI intervals to improve flow rates in the near-future. Any future development activities will be planned according to the results of the long-term test and further evaluation of the Mirador I to IV and Mirador VI intervals.
Current production after royalties is above 65,000 boe/d and is expected to increase throughout the fourth quarter. As part of the Company’s measures to sustain production from its core Quifa SW field, the first stage of the water handling expansion project is expected to start up by the end of October with full implementation by the end of the year, providing an additional 3,000 to 4,000 bbl/d of net oil production. The Company remains on track to deliver annual production at or close to the low end of the guidance range of 65,000 to 70,000 boe/d, despite three months of downtime related to pipeline issues in Peru (over 2,000 bbl/d impact on 2018 average production), a blockade in the first quarter at Cubiro in Colombia (approximately 500 bbl/d impact on 2018 average production) and higher than planned high price royalty payment volumes at Quifa (over 2,000 bbl/d impact on 2018 average production).
Fourth Quarter and 2019 Drilling Update
During the fourth quarter of 2018, the Company expects to drill 34 wells, with 18 development wells at Quifa SW, seven water injection wells, two development wells at Candelilla on the Guatiquia block, two development wells at Zopilote Sur on the Cravo Viejo block and five exploration and appraisal wells including;
Coralillo-3 (Guatiquia block): follow up appraisal well to the Coralillo-1 exploration well which tested over 1,000 bbl/d from the Lower Sand-1 formation and 800 bbl/d from the Guadalupe formation. The well was spud on October 8, and is expected to take 30 days to drill and 15 days to test.
Cocodrilo-1 (Guatiquia block): the third exploration target on the Guatiquia block in 2018, is targeted to spud in mid-November with drilling and testing operations complete by year end.
Jaspe-7D and Jaspe-8D (Quifa North area): two appraisal wells following up on the Jaspe-6D well drilled in January which tested at 187 bbl/d for 11 days. Jaspe 7D is expected to spud in the second half of December. With success, these appraisal wells will open up another large field development area in North Quifa adjacent to the Cajua field.
In 2019, the Company is planning to drill up to 10 exploration wells that will appraise recent new discoveries or target new prospects. New exploration projects include two exploration prospects on the Guama block, two exploration prospects on the Mapache block and two exploration prospects on the Sabanero block. The Company is considering participation in the Intracampos Bid Round in Ecuador, and any license round activities from the ANH in Colombia.