Fourth quarter production averaged 25,140 bopd, 1,194 bopd or 5 percent lower than the third quarter of 2012. Our Deep Llanos production decreased 1,643 bopd or nine percent mainly due to natural declines, partially offset by production additions from our Maya and Mambo discoveries. Central Llanos production increased 403 bopd or 11 percent primarily due to our Disa well coming back online for a full quarter after being offline for 88 days in the third quarter and production additions from our first horizontal development well on our Mantis field partially offset by natural declines. Our Neiva production decreased 396 bopd or 12 percent primarily as a result of well shut-ins due to facility constraints and natural declines since no development wells were drilled in the quarter. We plan to recommence our Neiva drilling programs in the second half of 2013. Orito production increased 442 bopd or 33 percent primarily due to the Orito-193 well that came online at the end of October. We recommenced our Orito developmental drilling program in December 2012.
Production has averaged 22,461 bopd to-date in the first quarter of 2013, 11 percent lower than fourth quarter production. Production was impacted by natural declines on our Yatay-1 well that are higher than our corporate average and certain wells being offline at Orito. This decrease was offset by the addition of 317 bopd of heavy oil from our Tatama-1 well coming on production.
Llanos Basin Heavy Oil Blocks (Rio Ariari, Chiguiro Oeste, Chiguiro Este), Colombia
In January, 2013, we successfully recommenced production testing our Tatama horizontal well and since then have produced over 25,000 barrels of 9 degree API oil, demonstrating a production methodology that supports proceeding towards commercialization. Once maximum available pump-rate was achieved, we produced the well at a stabilized average production rate of 556 bopd during a 28 day period with an average watercut of 86 percent and a 30 percent drawdown. The producing interval was the Mirador Formation. During the test, we observed an improving productivity index and a corresponding improvement in inflow efficiency, demonstrating positive reservoir response. As a result, we are re-equipping the well with a larger pump to test the well for an additional 48 days, which is the limit of our existing water disposal permit. We then plan to drill a second horizontal well in the Mochelo area to confirm the southern extension of the oil pool and test the productivity of a more optimally designed horizontal well that should provide the basis for a first phase commercial development.
Deep Llanos Basin (Corcel, Guatiquia and South Block 31), Colombia
We completed the evaluation of two exploration wells, Mapanare-1 on our Guatiquia Block and Amarillo-2 on our Corcel Block. Our Mapanare-1 test results were inconsistent with our petrophysical interpretation of the well that indicated a hydrocarbon bearing section in both the Mirador and Guadalupe formations. The Mirador Formation tested wet while the Guadalupe Formation test recovered two percent oil cut (or trace amounts) of 10 degree API gravity oil. As a result, the well has been abandoned. We are evaluating the inconsistencies between our test results and our geophysical analysis.
The petrophysical interpretation of our Amarillo-2 well indicated no net oil pay. We abandoned the well without testing, and have moved the rig to our Taya exploration prospect on the Corcel Block where we have commenced drilling. This well is targeting a large stratigraphic trap and with success could have multiple follow-up locations.
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