Frontera Announces Third Quarter 2020 Results
Strong Stable Cash Position with Increased Production Volumes
TORONTO, Nov. 4, 2020 /PRNewswire/ - Frontera Energy Corporation (TSX: FEC) ("Frontera" or the "Company") today reported financial and operational results for the third quarter ended September 30, 2020. All financial amounts in this news release are in United States dollars, unless otherwise stated. During the third quarter, the Company acquired control of Infrastructure Ventures Inc. ("IVI"), the parent company of Puerto Bahia which owns and operates a bulk liquid and dry cargo port in Cartagena, Colombia. As a result, the Company now fully consolidates IVI's results in the Financial Statements, impacting the comparability of various financial metrics. Please see the section entitled the Acquisition of Infrastructure Ventures Inc ("IVI") in the Financial Statements for full details.
Third Quarter Operational and Financial Results:
-- Third quarter production averaged 43,202 boe/d, all from Colombia,
compared to second quarter 2020 production of 42,597 boe/d. In August,
the Company brought back online most of the Colombian fields which it
had shut-in earlier in the year. In Peru Block 192, production remained
closed during the third quarter.
-- The Company reported a net loss of $90 million ($0.93/share), compared
to a net loss of $68 million ($0.70/share) in the second quarter of
2020. The loss in 3Q was primarily related to non-cash adjustments due
to the acquisition of IVI.
-- Production costs in the third quarter averaged $8.97/boe, compared to
$9.03/boe in the second quarter of 2020 reflecting the Company's success
in controlling costs in the current environment.
-- Transportation costs averaged $9.89/boe in the third quarter, compared
to $11.28/boe in the second quarter of 2020 largely as a result of the
consolidation of IVI. In the third quarter of 2020, the acquisition of
IVI lowered reported transportation costs by $0.94/boe compared to the
second quarter of 2020. In addition, we have reclassified $8 million in
third quarter expenses ($20 million year-to-date 2020) related to
non-cash transportation ancillary contracts to Costs under terminated
pipeline contracts.
-- General & Administrative Expenses were $10.5 million in the third
quarter, compared to $9.7 million in the second quarter, reflecting $1.2
million in additional costs as a result of the IVI consolidation.
-- Operating EBITDA was $52 million compared to $38 million in the second
quarter of 2020. Revenue increased due to sales volumes deferred from
the second quarter (which resulted in an additional cargo in the third
quarter) and improved Brent prices. In addition, production and
transportation costs improved in the quarter.
-- Capital expenditures in the third quarter were $3 million, versus $16
million in the second quarter of 2020 as the Company's focused on
conserving cash during the quarter.
-- The Company ended the third quarter of 2020 with total cash of $421
million, as compared to $395 million in the previous quarter. Of total
cash, at the end of the third quarter, restricted cash totaled $161
million as compared to $139 million at the end of the second quarter of
2020. The consolidation of IVI resulted in an increase of $26 million of
restricted cash and $2 million of cash and cash equivalents.
-- The Company's total debt and lease liabilities ended the third quarter
of 2020 at $557 million, including an increase in debt and lease
liabilities due to the consolidation of $203 million of 2025 Puerto
Bahia debt as a result of the IVI acquisition. The bank loan is
non-recourse to Frontera (other than as provided for by the equity
contribution agreement). Net debt (ex. Unrestricted Subsidiaries) was
$113 million as of September 30, 2020.
Gabriel de Alba, Chairman of the Board of Directors, commented:
"Frontera continues to demonstrate operational and financial discipline against the backdrop of a difficult oil price environment. In the third quarter, the Company finished with higher production volumes, stable production costs, and a cash position virtually unchanged quarter over quarter. Purchasing a controlling interest in Puerto Bahia provides several benefits for Frontera: (i) it gives the Company authority to shape the strategic direction in order to release value from the port, and (ii) removes both the special voting provisions and a put option held by former shareholders which created potential uncertainty around the port. We believe the port is a unique asset, combining a liquids terminal with a dry cargo facility, in a strategic location. We will continue to explore means to maximize the value of the port, and Frontera's other midstream assets. Our focus in the fourth quarter remains on maintaining our production volumes and our strong balance sheet, while ensuring we are positioned for long-term growth and value creation."
Richard Herbert, Chief Executive Officer of Frontera, commented:
"In the third quarter, we brought back online and stabilized a portion of the production previously shut-in while maintaining the improvements in costs and processes achieved earlier in the year. Quarterly production was above the high end of our second half guidance while production costs remained stable. We achieved this while upholding our commitment to the health and well-being of our field and office staff and people in the local communities where we operate.
In Peru, with ongoing disruption caused by the pandemic and the closure of the Norperuano pipeline, we have maintained the fields in Block 192 shut-in throughout the quarter. Frontera has notified PeruPetro of the lifting of force majeure on July 30 and that the six-month extension of our service contract, which was negotiated in March, will now expire in February 2021.
We are affirming our guidance for the remainder of the year, adjusted for the recent consolidation of Puerto Bahia, as we expect stable operations and results for the remainder of 2020. Remaining work this year will include infrastructure investments in the Lower Magdalena Valley and other preparatory work in Colombia, Ecuador and Guyana for our future exploration and development projects. Our strategy is designed to give us flexibility for the future, depending on oil prices, while maintaining the highest capital discipline. We expect to release our 2021 capital budget and guidance in December."
Operational and Financial Summary:
Q3 2020 Q2 2020 Q3 2019
Operational Results
(1)
---
Average Production
Oil production -
Colombia
(bbl/d) 41,817 40,948 61,420
Oil production -Peru
(bbl/d) 6,510
Natural gas production
-Colombia
(boe/d) 1,385 1,649 2,283
Total (2)
(boe/d) (3) 43,202 42,597 70,213
Sales Volumes
Colombia
(boe/d) 40,445 35,963 53,802
Peru
(bbl/d) 576
Total
(boe/d) 40,445 35,963 54,378
Inventory Balance
Colombia
(bbl) 708,103 840,893 798,953
Peru
(bbl) 1,000,058 852,892 1,851,080
Total
(bbl 1,708,161 1,693,785 2,650,033
Operating Netback
Net sales realized
price (4)
($/boe) 36.31 34.62 53.21
Production costs (5)
($/boe) (8.97) (9.03) (11.60)
Transportation costs
(6)(7)
($/boe) (9.89) (11.28) (12.00)
Operating netback
(7)(8)
($/boe) 17.45 14.31 29.61
Financial Results
---
Oil and Gas Sales
($M) 149,474 81,701 289,641
Net sales (8)
($M) 135,123 113,313 266,217
Net (loss) income(9)
($M) (90,473) (67,760) (49,117)
Per share - basic
($) (0.93) (0.70) (0.50)
Per share - diluted
($) (0.93) (0.70) (0.50)
General and
administrative
($M) 10,539 9,716 18,476
Operating EBITDA
(7)(8)
($M) 52,113 37,608 124,586
Cash provided by
operating activities
(10)
($M) 35,929 102,256 124,289
Capital expenditures
(11)
($M) 2,905 15,651 70,761
Total cash, including
restricted cash
($M) 421,298 394,769 442,293
Working capital
($M) (78,911) 37,403 124,998
Total debt and lease
liabilities
($M) 557,182 379,790 404,815
Consolidated total
indebtedness
(Excluding
Unrestricted
Subsidiaries) (12)
($M) 352,058 373,363 388,766
Net debt (Excluding
Unrestricted
Subsidiaries) (12)
($M) 113,054 128,882 94,082
1. Results not comparable to previous
quarters due to IVI consolidation
2. Represents working interest
production before royalties and
total volumes produced from service
contracts. Refer to the "Further
Disclosures" section on page 25 of
the MD&A.
3. Boe has been expressed using the
5.7 to 1 Colombian Mcf/bbl
conversion standard required by the
Colombian Ministry of Mines &
Energy.
4. Per boe is calculated using sales
volumes from development and
producing ("D&P") assets.
5. Per boe is calculated using
production.
6. Per boe is calculated using net
production after royalties.
7. For the second quarter of 2020 the
cost of the BIC Ancillary Agreements
and CLC Ancillary Agreements
cancelled and unpaid were
reclassified as Cost Under
Terminated Pipeline Contracts, refer
to "Commitments and Contractual
Obligations" section on page 20 of
the MD&A for further details.
8. Refer to the "Non-IFRS Measures"
section on page 15 of the MD&A. This
section also includes a description
and details for all per boe metrics
included in operating netback.
9. Net (loss) income attributable to
equity holders of the Company.
10. Figures for 2019 have been
revised to reflect the change in the
accounting policy of interest paid
as a financing activity instead of
an operating activity. For further
information on this adjustment,
refer to Note 3b of the 2019 Annual
Consolidated Financial Statements.
11. Capital expenditures includes
costs, net of income from
exploration and evaluation ("E&E")
assets.
12. Refer to the "Non-IFRS Measures"
section on page 15 of the MD&A.
("Unrestricted Subsidiaries")
include CGX Energy Inc.("CGX"),
Pacific Midstream Ltd., and Pacinfra
Holding Ltd ("Pacinfra", including
its subsidiary IVI).
Operational Update:
In the upstream heavy oil business unit, we reactivated CPE-6 and the Quifa satellite Cajua field during the third quarter. Subsequently, the Sabanero block was shut-in due to ongoing issues partially stemming from Covid-19, in the surrounding communities.
In the light and medium district, we reactivated the Cubiro, Casimena, and Canaguaro blocks during the quarter. Subsequently, we performed successful workovers and stimulations on several key wells including Ardilla-3, Yatay-2, and Candelilla-6 wells.
Capital expenditures were $3 million in the quarter as stable production allowed us to defer some well service and workovers into the fourth quarter. In the fourth quarter, Frontera expects to ramp up activity and capital expenditures, including workover / well service work in key oil fields in Colombia and to begin construction on facilities in the Lower Magdalena Valley ("VIM"), well test in Asai and other projects in anticipation of next year's development plans. The Company initiated work with 1 rig in the third quarter and expects to have 4 rigs running during the quarter.
In Ecuador, Frontera continues working to obtain environmental permits to start exploration activities in the Perico block. The permit is expected to be received in late 2020 and the first well is planned for drilling in late 2021.
Operational activities in Guyana have been affected throughout most of 2020 due to the COVID-19 Pandemic. Our Joint Venture with CGX Energy continues to have constructive collaborative discussions with the regulatory authorities in Guyana regarding work commitments in that country.
In our midstream business, as previously disclosed, on August 6, 2020, Frontera closed an agreement with the International Finance Corporation and related funds (the "IFC") to purchase all of IFC's interests in IVI. IVI is the parent company of Sociedad Portuaria Puerto Bahia ("Puerto Bahia"), which owns and operates a bulk liquid and dry cargo port in Cartagena, Colombia. The acquisition terminated a put option and special governance rights held by the IFC. Therefore, Frontera has acquired control over the future strategic direction of the port with a view to unlocking material value for the Company. Frontera, through its wholly owned subsidiary Pacinfra, now owns approximately 71.57% of the issued and outstanding shares of IVI and as a result from the third quarter of this year is consolidating IVI in its financial results.
Financial Liquidity:
As of the third quarter of 2020, the Company now consolidates IVI / Puerto Bahia, including its $203 million of debt (non-recourse to Frontera) and $26 million of restricted cash.
The Company's debt as of September 30, 2020, is outlined in the table below.
($M) 3Q 2020 2Q 2020
---
Gross Debt
(1)(2) $
557 $
380
(-) 2025
Puerto
Bahia Debt $
203
$
(+) Risk
Management
Assets, net
(3) $
(2) $
(7)
=
Consolidated
Total
Indebtedness
excluding
2025 Puerto
Bahia Debt
(4) $
352 $
373
(-) Cash and
Cash
Equivalents
(excluding
unrestricted
subsidiaries)
(5) $
239 $
244
= Net Debt
excluding
2025 Puerto
Bahia Debt $
113 $
129
1. Gross debt is the sum of Long-
term debt, Borrowings (2025
Puerto Bahia Debt), and Lease
liabilities
2. Excludes $0.1 million of lease
liabilities attributable to the
Unrestricted Subsidiaries on the
third quarter
3. Excludes $15.0 million of risk
management liabilities
attributable to the Unrestricted
Subsidiaries on the third quarter
4. Consolidated Total Indebtedness
per Frontera 2023 indenture
definition
5. Excludes $21.0 million of cash
attributable to the Unrestricted
Subsidiaries.
Guidance Restatement for the Consolidation of IVI
On August 6, 2020, the Company released updated guidance for full-year and second-half 2020. At the time, the prevailing Brent oil price of close to $45/bbl was projected forward for the remainder of 2020. We are reaffirming our guidance only adjusting transportation costs for the acquisition of IVI and changes to accounting treatment of unused ancillary contracts. To make the guidance comparable given those changes, we have reduced transportation cost guidance in the full year by $2.0 per boe (to $11.0 - $12.0 per boe from $13.0 - $14.0 per boe) and in the second half by $4.0 per boe (to $9.5 - $10.5 per boe from $13.5 - $14.5 per boe).
Jan 1, 2020 - Jan 1, 2020 - Jul 1, 2020 - Jul 1, 2020 -
Dec 31, 2020 Sep 30, 2020 Dec 31, 2020 Sep 30, 2020
(Actuals)
(Full Year (Actuals) (Second Half
Guidance) Guidance)
Average Production
(1)
(boe/d)
46,000 - 48,000 49,765
40,000 - 43,000 43,202
Production Cost
($/boe)
$9.5 - $10.5 $10.48
$8.0 - $9.0 $8.97
Transportation Cost
($/boe)
$11.0 - $12.0 $11.36
$9.5 - $10.5 $9.89
Capital Expenditures
(2)
($M)
$100 - $120 $83.2
$20 - $40 $2.9
---
1. Does not assume any production
from Peru for July 1, 2020
through December 31, 2020.
2. Guidance includes Frontera's
estimate of its share of costs
of the 2020 Guyana exploration
program, as joint venture
partner, but does not include
the consolidation impact of CGX
share of those exploration
costs.
Sustainability Disclosures
During the third quarter, Frontera released its 2019 Sustainability Report along with a brand new ESG presentation, detailing its key environmental, social, and governance ("ESG") initiatives. The report and presentation are aligned with the Sustainability Accounting Standard Board framework and available at www.fronteraenergy.ca.
Hedging Update:
The goal of the hedging program is to protect the revenue generation and cash position of the Company. The forward hedging position was also increased in part to support restarting production and protect the break-evens of the previously shut-in fields. The Company has now hedged approximately 3.7 million bbls (approximately 100% of expected production) at Brent $35/bbl for the fourth quarter of 2020 and 3.8 million bbls at Brent $35 - $37/bbl for the first half of 2021.
The following is the current hedging portfolio as of the date of this release:
Term Type of Instrument Notional Amount / Put/Call/Spreads $/bbl
Volume (bbl)
--- ---
October
Put Spread 1,012,500
25/35
3-ways 269,000
27/37/49
---
Total October 1,281,500
November
Put Spread 946,500
25/35
3-ways 273,000
27/37/49
---
Total November 1,219,500
December
Put Spread 948,500
25/35
3-ways 251,000
27/37/49
---
Total December 1,199,500
Q4 2020 Total Q4 3,700,500
---
Total 2020 3,700,500
January
Put Spread 377,000
26.5/36.5
3-ways 296,000
25.5/35.5/50.4
---
Total January 673,000
February
Put Spread 366,800
26.5/36.5
3-ways 244,000
25.5/35.5/50.4
---
Total February 610,800
March
Put Spread 377,000
26.5/36.5
3-ways 300,000
25.5/35.5/50.4
---
Total March 677,000
Q1 2021 Total Q1 1,960,800
---
April
Put Spread 160,000
26.5/36.5
3-ways 457,000
25.5/35.5/51.8
---
Total April 617,000
May
Put Spread 160,000
26.5/36.5
3-ways 481,000
25.5/35.5/51.8
---
Total May 641,000
June
Put Spread 160,000
26.5/36.5
3-ways 452,000
25.5/35.5/51.8
---
Total June 612,000
Q2 2021 Total Q2 1,870,000
---
Total Average 2021 3,830,800
---
Third Quarter 2020 Conference Call Details
The Company will host a conference call for investors and analysts to discuss its results on Thursday, November 5, 2020 at 8:00 a.m. (MST) and 10:00 a.m. (EST/GMT-5). Participants should use the following dial-in numbers:
Participant Number
(Toll Free North
America):
1-888-664-6392
Participant Number
(Toll Free
Colombia):
01-800-518-4036
Participant Number
(International):
1-416-764-8659
Conference ID: 19881048
Webcast: https://produceredition.webcasts.com/starthere.jsp?ei=1383964&tp_key=732c45bd20
A replay of the conference call will be available until 11:59 p.m. (EST/GMT-5) Thursday, November 12, 2020.
Encore Toll free
Dial-in Number:
1-888-390-0541
International Dial-
in Number:
1-416-764-8677
Encore ID: 267364
About Frontera:
Frontera Energy Corporation is a Canadian public company and a leading explorer and producer of crude oil and natural gas, with operations focused in South America. The Company has a diversified portfolio of assets with interests in more than 40 exploration and production blocks in Colombia, Peru, Ecuador and Guyana. The Company's strategy is focused on sustainable growth in production and reserves. Frontera is committed to conducting business safely, ethically in a socially and environmentally responsible manner. Frontera's common shares trade on the Toronto Stock Exchange under the ticker symbol "FEC".
If you would like to receive News Releases via e-mail as soon as they are published, please subscribe here: http://fronteraenergy.mediaroom.com/subscribe.
Advisories:
Cautionary Note Concerning Forward-Looking Statements
This news release contains forward-looking statements. All statements, other than statements of historical fact, that address activities, events or developments that the Company believes, expects or anticipates will or may occur in the future (including, without limitation, statements regarding the impact of a sustained low price of oil and natural gas, the ongoing impact of the COVID-19 pandemic on the Company's operations, the effectiveness or adequacy of the measures that the Company's has taken and continues to take to manage the COVID-19 pandemic and current oil price environment, estimates and/or assumptions in respect of the Company's capital expenditure program (including Company's guidance), production, costs, future income generation capacity, cash levels, the Company's exploration and development plans and objectives, including its drilling plans and the timing thereof, regulatory approvals, the impact of shut-ins and other work in the field on future field performance, and the Company's hedging program and its ability to mitigate the impact of lower oil prices) are forward-looking statements. These forward-looking statements reflect the current expectations or beliefs of the Company based on information currently available to the Company. Forward-looking statements are subject to a number of risks and uncertainties that may cause the actual results of the Company to differ materially from those discussed in the forward-looking statements, and even if such actual results are realized or substantially realized, there can be no assurance that they will have the expected consequences to, or effects on, the Company. Factors that could cause actual results or events to differ materially from current expectations include, among other things: volatility in market prices for oil and natural gas (including as a result of a sustained low oil price environment due to the COVID-19 pandemic and the actions of OPEC and non-OPEC countries and the procedures imposed by governments in response thereto; the duration and spread of the COVID-19 pandemic and its severity, the success of the Company's program to manage COVID-19; uncertainties associated with estimating and establishing oil and natural gas reserves and resources; liabilities inherent with the exploration, development, exploitation and reclamation of oil and natural gas; uncertainty of estimates of capital and operating costs, production estimates and estimated economic return; increases or changes to transportation costs; expectations regarding the Company's ability to raise capital and to continually add reserves through acquisition and development; the Company's ability to access additional financing; the ability of the Company to maintain its credit ratings; the ability of the Company to: meet its financial obligations and minimum commitments, fund capital expenditures and comply with covenants contained in the agreements that govern indebtedness; political developments in the countries where the Company operates; the uncertainties involved in interpreting drilling results and other geological data; geological, technical, drilling and processing problems; timing on receipt of government approvals; fluctuations in foreign exchange or interest rates and stock market volatility and the other risks disclosed under the heading "Risks and Uncertainties" in the Company's MD&A dated November 3, 2020 and under the heading "Risk Factors" and elsewhere in the Company's annual information form dated March 5, 2020 filed on SEDAR at www.sedar.com. Any forward-looking statement speaks only as of the date on which it is made and, except as may be required by applicable securities laws, the Company disclaims any intent or obligation to update any forward-looking statement, whether as a result of new information, future events or results or otherwise. Although the Company believes that the assumptions inherent in the forward-looking statements are reasonable, forward-looking statements are not guarantees of future performance and accordingly undue reliance should not be put on such statements due to the inherent uncertainty therein.
This news release contains future oriented financial information and financial outlook information (collectively, "FOFI") (including, without limitation, statements regarding expected average production, production costs, transportation costs, capital expenditures, total cash and cash and cash equivalents), and are subject to the same assumptions, risk factors, limitations and qualifications as set forth in the above paragraph. The FOFI has been prepared by management to provide an outlook of the Company's activities and results, and such information may not be appropriate for other purposes. The Company and management believe that the FOFI has been prepared on a reasonable basis, reflecting management's reasonable estimates and judgments, however, actual results of operations of the Company and the resulting financial results may vary from the amounts set forth herein. Any FOFI speaks only as of the date on which it is made and the Company disclaims any intent or obligation to update any FOFI, whether as a result of new information, future events or results or otherwise, unless required by applicable laws.
Non-IFRS Financial Measures
This news release contains financial terms that are not considered in the International Financial Reporting Standards ("IFRS"): Operating EBITDA, Operating Netback, Net Sales, Consolidated Total Indebtedness and Net Debt. These financial measures, together with measures prepared in accordance with IFRS, provide useful information to investors and shareholders, as management uses them to evaluate the operating performance of the Company. The Company's determination of these non-IFRS measures may differ from other reporting issuers, and therefore are unlikely to be comparable to similar measures presented by other companies. Further, these non-IFRS measures should not be considered in isolation or as a substitute for measures of performance or cash flows prepared in accordance with IFRS. These financial measures are included because management uses this information to analyze operating performance and liquidity.
Operating EBITDA
Management believes that EBITDA is a common measure used to assess profitability before the impact of different financing methods, income taxes, depreciation and impairment of capital assets and amortization of intangible assets.
EBITDA is a commonly used measure that adjusts net income (loss) as reported under IFRS to exclude the effects of income taxes, finance income and depletion, depreciation and amortization expense.
Operating EBITDA represents the operating results of the Company's primary business, excluding the items noted above, restructuring, severance and other costs, certain non-cash items (such as impairments, foreign exchange, unrealized risk management contracts, costs under terminated pipeline contracts, and share-based compensation) and gains or losses arising from the disposal of capital assets. In addition, other unusual or non-recurring items are excluded from operating EBITDA, as they are not indicative of the underlying core operating performance of the Company.
A reconciliation of Operating EBITDA to net loss is as follows:
Three Months Ended
($M) September June 30, September
30, 2020 30, 2019
2020
---
Net (loss) income (90,473) (67,760) (49,117)
Costs under
terminated
pipeline
contracts(1) 8,391 8,391
Share-based
compensation 246 1,316 1,314
Depletion,
depreciation and
amortization 60,960 58,250 94,019
Impairment 480 3,329 44,822
Restructuring,
severance and
other costs 1,047 6,302 5,463
Share of income
from associates (15,193) (23,336) (17,183)
Foreign exchange
loss 12,450 2,535 3,735
Finance income (2,019) (6,167) (5,580)
Finance expenses 12,655 11,728 19,732
Unrealized loss
(gain) on risk
management
contracts 351 36,011 (4,338)
Other loss, net 38,626 2,668 1,359
Income tax expense 2,805 1,161 29,899
Non-controlling
interests (2,169) 3,180 461
Reclassification
of currency
translation
adjustments 23,956
---
Operating EBITDA 52,113 37,608 124,586
---
1. For the second quarter of 2020
the cost of the BIC Ancillary
Agreements and CLC Ancillary
Agreements cancelled and unpaid
were reclassified as Cost Under
Terminated Pipeline Contracts,
refer to "Commitments and
Contractual Obligations" section on
MD&A.
2020 2019
($M) Q3 Q2 Q1 Q4 Q3 Q2 Q1
---
Financial and
Operational
results:
Operating EBITDA 52,113 37,608 46,982 137,052 124,586 179,665 144,855
---
Netbacks
Management believes that Netback is a useful measure to assess the net profit after all the costs associated with bringing one barrel of oil to the market. It is also commonly used by the oil and gas industry to analyze financial and operating performance expressed as profit per barrel. Operating Netback represents realized price per barrel plus realized gain or loss on financial derivatives, less production costs, transportation costs, royalties, and diluent costs, and shows how efficient the Company is at extracting and selling its product. For netback purposes, the Company removes the effects of trading activities and Midstream segment from its per barrel metrics. Refer to the "Operating Netback" section on page 6 of the MD&A.
Net Sales
Net sales is a non-IFRS subtotal that adjusts revenue to include realized gains and losses from risk management contracts while removing the cost of dilution activities. This is a useful indicator for management as the Company hedges a portion of its oil production using derivative instruments to manage exposure to oil price volatility. This metric allows the Company to report its realized net sales after factoring in these risk management activities. The deduction of diluent cost is helpful to understand the Company's sales performance based on the net realized proceeds from production net of dilution, the cost of which is partially recovered when the blended product is sold. Net sales exclude sales from port services, as it is not considered part of the oil & gas segment, and sales and purchases of oil and gas for trading as the gross margins from these activities are not considered significant or material to the Company's operations. Refer to the reconciliation in the "Sales" section on page 7 of the MD&A.
Consolidated Total Indebtedness and Net Debt
Consolidated total indebtedness and net debt are used by the Company to monitor its capital structure, financial leverage, and as a measure of overall financial strength. Consolidated total indebtedness is defined as long-term debt, plus liabilities for leases and net position of risk management contracts, excluding Unrestricted Subsidiaries. This metric is consistent with the definition under the Company's Unsecured Notes (as defined in the MD&A) for the calculation of certain conditions and covenants. Net debt is defined as consolidated total indebtedness less cash and cash equivalents. Both measures are exclusive of non-recourse subsidiary debt (2025 Puerto Bahia Debt) and cash attributable to the Unrestricted Subsidiaries.
Please see the MD&A for additional information about these financial measures.
Oil and Gas Information Advisories
Reported production levels may not be reflective of sustainable production rates and future production rates may differ materially from the production rates reflected in this news release due to, among other factors, difficulties or interruptions encountered during the production of hydrocarbons.
The term "boe" is used in this news release. Boe may be misleading, particularly if used in isolation. A boe conversion ratio of cubic feet to barrels is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. In this news release, boe has been expressed using the Colombian conversion standard of 5.7 Mcf: 1 bbl required by the Colombian Ministry of Mines and Energy.
Definitions:
bbl(s)
Barrel(s) of oil
bbl/d
Barrel of oil per day
boe Refer to "Boe Conversion"
disclosure above
boe/d Barrel of oil equivalent per day
Mcf
Thousand cubic feet
---
Net Production Net production represents the
Company's working interest
volumes, net of royalties and
internal consumption
---
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SOURCE Frontera Energy Corporation
