CANACOL ENERGY LTD Charle Gamba, President and CEO of Canacol, stated: 'I'm pleased to report that during the quarter ended September 30, 2015, the Clarinete-2 ST appraisal well was drilled confirming a significant gas discovery at Clarinete. The well encountered 127 feet of net gas pay within the main Cienaga de Oro reservoir target and, in October 2015, the well tested at a final gross rate of 25.6 million standard cubic feet per day ('MMscfpd') (4,491 barrels of oil equivalent per day 'boepd') of dry gas with no water from the Cienaga de Oro reservoir, and at a final gross rate of 4.7 MMscfpd (825 boepd) of dry gas with 1 barrel of water from the overlying Tubara sandstone reservoir.
I'm also pleased to report that during the quarter ended September 30, 2015, the Corporation and its joint venture operating partners completed the testing of the successful Secoya Oeste - A001 exploration well located adjacent to the producing Libertador and Atacapi light oil fields in the Oriente Basin of Ecuador. The well encountered 33 feet of net oil pay within the T, U, and basal Tena sandstone reservoirs. The Lower U sandstone reservoir tested at an average gross rate of 972 barrels of oil per day ('bopd') (243 bopd net) of 27° API oil with a 10% water cut over the course of a 50 hour test using a jet pump. The Upper U sandstone tested at an average gross rate of 326 bopd (82 bopd net) of 29° API oil with 8% water cut over the course of a 53 hour test using a jet pump.
The Corporation grew average production for the three months ended September 30, 2015 to 10,455 boepd, a 5% increase over the previous quarter ended June 30, 2015, primarily due to Canacol's successful LLA-23 workover program for light oil.
For the three months ended September 30, 2015, the Corporation reduced production and transportation expenses by 57% to $7.26/boe compared $17.01/boe for the comparable period. The decrease is primarily due to the Corporation's cost-cutting initiatives of centralizing the production, loading, and water disposal operations from the different fields within the LLA-23 block to the Pointer platform.
On the financing front, in early September 2015, Canacol announced a strategic private placement with Cavengas Holding S.R.L. ('Cavengas') for C$79 million (approximately $60 million), which allowed for both a partial debt repayment of $20 million and the ability to maintain a flexible capital expenditure program as the Corporation continues to focus on developing its substantial natural gas portfolio. As part of this transaction, we are very pleased to have Mr. Cisneros and Mr. Sosa join the board of Canacol. Both are consummate businessmen whom will broaden the depth of the board of directors, and leverage their extensive relationships in South America to bring new projects to the Corporation's portfolio. After having prepaid a portion of our debt, Canacol exited the quarter with $48.5 million in cash and an additional $61.3 million of restricted cash. Subsequent to September 30, 2015, we closed on the final portion of the Cavengas investment, bringing a further $33 million into the Corporation.'
Highlights for the three months ended September 30, 2015(Production is stated as working-interest before royalties)
Financial and operational highlights of the Corporation include:
The Clarinete-2 ST appraisal well encountered 127 feet of net gas pay within the main Cienaga de Oro reservoir target, confirming a significant gas discovery at Clarinete. In October 2015, the Clarinete-2 ST appraisal well was tested at a final gross rate of 25.6 MMscfpd (4,491 boepd) of dry gas with no water from the Cienaga de Oro reservoir, and at a final gross rate of 4.7 MMscfpd (825 boepd) of dry gas with 1 barrel of water from the overlying Tubara sandstone reservoir.
Production expenses decreased 15% to $6.4 million for the three months ended September 30, 2015 compared to
$7.5 million for the three months ended June 30, 2015, even though production increased from 9,961 boepd to 10,455 boepd. Despite a 28% decrease in LLA-23 oil production year over year, the production expenses have dropped to $7.52/bbl, down 56% from the $17.07/bbl posted for the same quarter in 2014. The decrease is primarily due to the Corporation's cost-cutting initiatives of centralizing the production, loading, and water disposal operations from the different fields within the LLA-23 block to the Pointer platform, lower renegotiated operating costs, and the devaluation of the Colombian peso versus the United States dollar.
Despite a 15% decrease in gas sales by volume due to pipeline capacity being down for further construction, average daily sales volumes increased 5% to 10,727 boepd for the three months ended September 30, 2015 compared to 10,256 boepd for the three months ended June 30, 2015 as a result of the Corporation's successful LLA-23 workover program and its light oil discovery in Ecuador during the quarter.
Petroleum and natural gas revenues for the three months ended September 30, 2015 decreased 20% to $22.0 million compared to $27.3 million for the three months ended June 30, 2015. Adjusted petroleum and natural gas revenues, inclusive of revenues related to the Ecuador Incremental Production Contract (the 'Ecuador IPC') (see full discussion in MD&A), for the three months ended September 30, 2015 decreased 12% to $29.9 million compared to $33.9 million for the three months ended June 30, 2015. The decrease in revenues reflects decrease in benchmark crude oil prices over the respective periods.
Average corporate operating netback for the three months ended September 30, 2015 decreased 15% to
$22.73/boe compared to $26.68/boe for the three months ended June 30, 2015. The decrease in average corporate operating netback is mainly attributable to decrease in benchmark crude oil prices, offset by reductions in production and transportation expenses per boe. Average corporate operating netbacks are inclusive of results from the Ecuador IPC.
Adjusted funds from operations for three months ended September 30, 2015 decreased 7% to $15.2 million compared to $16.4 million for the three months ended June 30, 2015. Adjusted funds from operations are inclusive of results from the Ecuador IPC. The decrease in adjusted funds from operation is primarily the result of decrease in benchmark crude oil prices.
The Corporation had a net loss of $19.0 million for the three months ended September 30, 2015 compared to net loss of $58.5 million for the three months ended June 30, 2015. The net loss is mainly driven by non-cash expenses such as depletion and depreciation, stock-based compensation, and deferred income tax expense.
Capital expenditures for the three months ended September 30, 2015 was $22.3 million, while adjusted capital expenditures, inclusive of amounts related to the Ecuador IPC, was $26.1 million.
On September 3, 2015, the Corporation completed a private placement with Cavengas for the amount of C$79 million, being a 19.9% investment in the Corporation. C$35 million was released on that date, with the remaining C$44 million closed on October 16, 2015.
At September 30, 2015, the Corporation had $48.5 million in cash and cash equivalents and $61.3 million in restricted cash.
On September 30, 2015, the Corporation pre-paid $20 million on its BNP Senior Secured Term Loan, bringing the balance outstanding to $180 million.
Financial
Three months ended September 30,
2015
2014
Change
Petroleum and natural gas revenues, net of royalties
21,958
58,917
(63%)
Adjusted petroleum and natural gas revenues, net of royalties, including revenues related to the Ecuador IPC (2)
29,899
67,356
(56%)
Cash provided by operating activities
14,302
45,618
(69%)
Per share
- basic ($)
0.11
0.42
(72%)
Per share
- diluted ($)
0.11
0.42
(72%)
Adjusted funds from operations (1)(2)
15,218
37,162
(59%)
Per share
- basic ($)
0.12
0.34
(65%)
Per share
- diluted ($)
0.12
0.34
(65%)
Net income (loss)
(19,029)
14,110
n/a
Per share
- basic ($)
(0.15)
0.13
n/a
Per share
- diluted ($)
(0.15)
0.13
n/a
Capital expenditures, net, including acquisitions
22,299
47,522
(53%)
Adjusted capital expenditures, net, including acquisitions and capital expenditures related to the Ecuador IPC (1)(2)
26,080
56,209
(54%)
Cash and cash equivalents
September 30, 2015
June 30, 2015
Change
48,493
45,765
6%
Restricted cash
61,316
61,772
(1%)
Working capital surplus, excluding the current portion of bank debt and non-cash items (1)
50,152
62,883
(20%)
Short-term and long-term bank debt
247,639
267,023
(7%)
Total assets
672,628
669,742
0%
Common shares, end of period (000's)
140,926
126,434
11%
Operating
Three months ended September 30,
2015
2014
Change
Petroleum and natural gas production, before royalties (boepd)
6,983
Petroleum (3)
9,922
(30%)
Natural gas
3,472
3,334
4%
Total (2)
10,455
13,256
(21%)
Petroleum and natural gas sales, before royalties (boepd)
7,272
Petroleum (3)
9,997
(27%)
Natural gas
3,455
3,311
4%
Total (2)
10,727
13,308
(19%)
Realized sales prices ($/boe)
34.01
LLA-23 (oil)
83.97
(59%)
Esperanza (natural gas)
26.61
21.48
24%
Ecuador (tariff oil) (2)
38.54
38.54
-
Total (2)
33.00
60.15
(45%)
Operating netbacks ($/boe) (1)
19.75
LLA-23 (oil)
54.03
(63%)
Esperanza (natural gas)
22.54
16.84
34%
Ecuador (tariff oil) (2)
38.54
38.54
-
Total (2)
22.73
37.70
(40%)
Non-IFRS measure - see 'Non-IFRS Measures' section within MD&A.
Inclusive of amounts related to the Ecuador IPC - see 'Non-IFRS Measures' section within MD&A.
Includes tariff oil production and sales related to the Ecuador IPC.
The three months ended September 30, 2015 was a very strong quarter for Canacol, both operationally and financially. Operationally, we confirmed our significant gas discovery at Clarinete via a step out well with 127 feet of net gas pay, and flow rates in excess of 30 MMscfpd. We also had an oil discovery in our Ecuador joint venture and decreased our Colombian LLA-23 production costs to less than half of what they were a year ago on a per boe basis. Financially, we arranged a C$79 million investment from our new strategic investor Cavengas, as well as prepaying $20 million on our debt facilities, both ensuring the Corporation remains in a very strong financial position to develop its substantial natural gas portfolio.
Canacol is also pleased to report that it has recently signed new gas sales contracts, bringing the new total 2016 maximum contracted gas to 90 MMscfpd upon the completion of the previously announced Promigas pipeline. The anticipated average contracted gas sales volumes for 2016 is now approximately 81 MMscfpd, as adjusted by the Promigas pipeline schedule discussed below. The average price of the 2016 natural gas sales contracts has now increased to approximately US$5.50/Mcf. The Corporation is seeing very strong demand for its natural gas in light of declining existing production in the region, as well as increasing thermo-electric growth at least partially driven by current El Nino conditions in the region.
The Corporation has also been informed by Promigas S.A. E.S.P. that due to operational delays in the expansion of the transportation capacity of the gas pipeline between Jobo and Cartagena, the new pipeline will begin operations with an additional capacity of 19 MMscfpd by December 30, 2015, total additional capacity of 50 MMscfpd by January 30, 2016, and total additional capacity of 65 MMscfpd by mid-February 2016. The Corporation's current and continuing production of approximately 25 MMscfpd will not be affected by the delays related to the pipeline expansion, as this gas is sold via a separate pipeline. The Jobo gas processing plant expansion and Clarinete field tie-in remain on schedule to be completed prior to the end of November, and the Oboe-1 well is currently scheduled to spud mid- November following the completion of rig maintenance.
* * *
The Corporation's has filed its unaudited interim condensed consolidated financial statements and related Management's Discussion and Analysis as of and for the three months ended September 30, 2015 with Canadian securities regulatory authorities. These filings are available for review on SEDAR at www.sedar.com.
Canacol is an exploration and production company with operations focused in Colombia and Ecuador. The Corporation's common stock trades on the Toronto Stock Exchange, the OTCQX in the United States of America, and the Colombia Stock Exchange under ticker symbols CNE, CNNEF, and CNEC, respectively.
This press release contains certain forward-looking statements within the meaning of applicable securities law. Forward-looking statements are frequently characterized by words such as 'plan', 'expect', 'project', 'intend', 'believe', 'anticipate', 'estimate' and other similar words, or statements that certain events or conditions 'may' or 'will' occur, including without limitation statements relating to estimated production rates from the Corporation's properties and intended work programs and associated timelines. Forward-looking statements are based on the opinions and estimates of management at the date the statements are made and are subject to a variety of risks and uncertainties and other factors that could cause actual events or results to differ materially from those projected in the forward-looking statements. The Corporation cannot assure that actual results will be consistent with these forward looking statements. They are made as of the date hereof and are subject to change and the Corporation assumes no obligation to revise or update them to reflect new circumstances, except as required by law. Information and guidance provided herein supersedes and replaces any forward looking information provided in prior disclosures. Prospective investors should not place undue reliance on forward looking statements. These factors include the inherent risks involved in the exploration for and development of crude oil and natural gas properties, the uncertainties involved in interpreting drilling results and other geological and geophysical data, fluctuating energy prices, the possibility of cost overruns or unanticipated costs or delays and other uncertainties associated with the oil and gas industry. Other risk factors could include risks associated with negotiating with foreign governments as well as country risk associated with conducting international activities, and other factors, many of which are beyond the control of the Corporation. Other risks are more fully described in the Corporation's most recent Management Discussion and Analysis ('MD&A') and Annual Information Form, which are incorporated herein by reference and are filed on SEDAR at www.sedar.com. Average production figures for a given period are derived using arithmetic averaging of fluctuating historical production data for the entire period indicated and, accordingly, do not represent a constant rate of production for such period and are not an indicator of future production performance. Detailed information in respect of monthly production in the fields operated by the Corporation in Colombia is provided by the Corporation to the Ministry of Mines and Energy of Colombia and is published by the Ministry on its website; a direct
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