Delaware | 98-0479924 |
(State or other jurisdiction of incorporation) | (I.R.S. Employer Identification No.) |
August 7, 2019 | GRAN TIERRA ENERGY INC. | |
/s/ Ryan Ellson | ||
By: Ryan Ellson | ||
Chief Financial Officer |
• | Net income was $39 million ($0.10 per share, basic) compared with a net income of $2 million or $0.01 per share basic in the quarter ended March 31, 2019 ("the Prior Quarter"); net income for the first six months of 2019 was $41 million |
• | EBITDA(1) increased by 24% to $115 million, up from $93 million in the Prior Quarter; for the first six months of 2019, the Company has generated EBITDA of $208 million |
• | Funds flow from operations(1) increased by 17% to $88 million ($0.23 per share, basic) compared with $75 million ($0.19 per share, basic) in the Prior Quarter; funds flow from operations for the first six month of 2019 was $164 million |
• | Returned $24 million to stockholders between January 1 and June 30, 2019, through buybacks of 10.4 million shares of common stock (2.7% of outstanding shares of common stock as of January 1, 2019) |
• | At June 30, 2019, net debt(1) to EBITDA was 1.4 times on a trailing 12 month basis (on a trailing 12 month basis, net income was $105 million and EBITDA was $394 million) and 1.2 times on the basis of the Quarter's annualized results |
• | Achieved return on average capital employed(1) of 15.5% during the Quarter |
• | Oil and gas sales increased by $5 million to $158 million, up from $153 million in the Prior Quarter |
• | Operating netback(1) per BOE increased by 10%, compared with the Prior Quarter, to $33.02 per BOE |
• | Subsequent to the end of the Quarter, Gran Tierra successfully repurchased and canceled $114,997,000 out of its $115,000,000 convertible notes outstanding, limiting future potential dilution |
• | Acordionero-48 Well Results: this well encountered 77 feet of oil pay within the new Lisama E Sand, in an over-pressured reservoir; on production test using a jet pump, this well has produced as follows: |
◦ | During 115 producing hours (August 1-7, 2019), the well averaged 509 bbls of oil per day ("bopd") of 24 degree API oil, a watercut of 5.2% and a gas-oil ratio ("GOR") of 153 standard cubic feet per stock tank bbl ("scf/stb") |
◦ | In the last 24 hours (August 6-7, 2019), the well averaged 751 bopd of 24 degree API oil, a watercut of 0.4% and a GOR of 115 scf/stb |
◦ | The Lisama E is located just below the main Lisama A and C reservoirs, and although penetrated with other wells in the Acordionero field, this well was the first opportunity for the Company to test this new reservoir horizon |
• | Successful Expansion of Acordionero Facilities: the commissioning of the expansion of Acordionero's central processing and water injection facilities, as well as the installation of gas-to-power turbines ("Acordionero Facilities Projects"), are complete, allowing for a total oil production capacity of approximately 30,000 bopd |
• | Acordionero Water Injection: has increased to approximately 28,500 bbls of water injected per day ("bwipd") during the May to July 2019 timeframe; the water source, handling, and injection system has been successfully tested at 40,000 bwipd and is expected to increase to that level on a sustained basis during August 2019; with the planned increase in water injection, Gran Tierra forecasts a positive impact on reservoir pressure, supporting increased oil production rates from current and future oil producers and ultimate oil recovery efficiency from all of the reservoirs |
• | The Quarter's Average Production: was 35,340 BOE per day ("BOEPD"), which was impacted by the temporary issues previously discussed in the Company's operations update press releases on June 18, 2019 and July 10, 2019 |
• | Updated 2019 Guidance: the Company has revised its expected 2019 production, total capital and cash flow guidance to ranges of 36,500-37,500 BOEPD, $330-340 million and $335-355 million, respectively |
• | The Mono Araña-3 Well: was drilled as an extension/appraisal of the field and encountered 125 feet of oil pay in the Lisama A Sand and 27 feet of oil pay in the Lisama C Sand; the well has been completed and is expected to be placed on production test imminently |
• | Southern Putumayo Production: Gran Tierra has continued to produce approximately 4,500 BOEPD uninterrupted since the end of the Quarter from the Suroriente and PUT-7 Blocks, where a temporary blockade impacted production during the Quarter |
• | New Colombian Exploration Acreage: Gran Tierra has won two blocks in the recent Agencia Nacional de Hidrocarburos ("ANH") bid round in Colombia, the LLA-85 Block in the Llanos Basin and the VMM-24 Block in the Middle Magdalena Valley ("MMV") Basin |
• | Ecuador Exploration Acreage: during the Quarter, Gran Tierra officially signed contracts for the Company's three exploration blocks in Ecuador, which are contiguous to Gran Tierra's Putumayo Basin assets in Colombia |
2019 Budget | Previous | Revised | ||
Production (BOEPD) | 41,000-43,000 | 36,500-37,500 | ||
Brent Oil Price ($/bbl) | 65.00 | 65.00 | ||
Cash Flow(1) ($ million) | 375-395 | 335-355 | ||
Total Capital ($ million), Excluding Acquisition | 320-340 | 330-340 | ||
Development Capital ($ million) | 215-225 | 230-235 | ||
Exploration Capital ($ million) | 105-115 | 100-105 | ||
Number of Development Wells (gross) | 26-30 | 28-32 | ||
Number of Exploration Wells (gross) | 6-8 | 4-5 |
2019 Budget | Previous | Revised | ||
Brent Oil Price ($/bbl) | 65.00 | 65.00 | ||
Expenses ($/boe) | ||||
Transportation & Quality Discount | 11.00 - 13.00 | 10.00 - 11.00 | ||
Royalties | 9.00 - 10.00 | 9.00 - 10.00 | ||
Oil and Gas Sales Price ($/boe) | 42.00 - 45.00 | 44.00 - 46.00 | ||
Operating Costs | 9.00 - 10.00 | 11.00 - 12.00* | ||
Transportation (Pipeline) | 1.50 - 2.00 | 1.50 - 2.00 | ||
Operating Netback(1,2) ($/boe) | 30.00 - 34.50 | 30.00 - 34.50 |
• | Gran Tierra has ICE Brent oil hedges in place covering 10,000 bopd of production for the remainder of 2019 with a floor price of $60 per bbl |
• | Additional information on the Quarter's expenses: |
◦ | Transportation Expenses: decreased by 36% to $1.51 per BOE from $2.35 per BOE in the Prior Quarter |
◦ | Operating Expenses: increased to $10.44 per BOE compared with $10.09 per BOE in the Prior Quarter, primarily due to lower production during the Quarter; these expenses are expected to decrease with the successful commissioning of the Acordionero Facilities Projects |
◦ | Workover Expenses: increased by 117% to $3.95 per BOE compared with $1.82 per BOE in the Prior Quarter, primarily attributable to increased pump failures due to unreliable power and higher GOR at Acordionero; these expenses are expected to decline due to the start-up of Acordionero's gas-to-power project and the increase in Acordionero's water injection, which is forecasted to address the GOR issues |
• | The Cohembi oil field in the Suroriente Block continues to respond positively to increased water injection and pump optimizations; gross water injection is currently averaging 18,700 bwipd (up from 14,500 bwipd when Gran Tierra assumed operatorship on March 1, 2019); the Company is planning to increase gross water injection to 40,000 bwipd by the end of 2019 |
• | As part of an expanded waterflood program, activities have commenced with the expansion of the Cohembi water treatment, injection and processing facilities; the expansion is expected to boost water injection capacity from a current 19,000 bwipd to 60,000 bwipd; targeted completion for the first phase of expansion is scheduled to be in fourth quarter 2019 |
• | The new CYC-39 well was targeting suspected unswept T and Caballos Sands in the southern part of the Costayaco field: |
◦ | From July 19 to August 4, 2019, the well produced commingled from both zones at stabilized averages of 670 bopd of 30 degree API oil, a GOR of 129 scf/stb and a watercut of 23% on jet pump |
◦ | Pressure build up tests were run on both zones during their individual production tests; pressure transient analysis indicates that the Caballos Sand may have skin damage |
◦ | The well was shut in on August 5, 2019, in order to conduct a planned stimulation of the Caballos Sand, after which the Company intends to run an electric submersible pump to produce the two zones commingled |
• | For the remainder of 2019, the Company intends to complete the drilling of the CYC-40 infill well and to stimulate three wells (CYC-25. 18, 12i) and convert CYC-35 to injection |
• | The appraisal program has commenced with the completion of Mono Araña-3; four additional development/appraisal wells are planned for the remainder of 2019 |
• | The Company has awarded a contract to import a snubbing unit (equipment capable of working with high pressures) to retrieve parted coiled tubing in both the AY-2 and 3 wells in order to continue with completion operations |
• | The AY-1 well continues to produce on natural flow; during the month of July 2019, the well averaged 214 bopd of 18 degree API oil, a watercut of 0.1%, a GOR of 145 scf/stb and 1,521 pounds per square inch of tubing head pressure |
• | Gran Tierra remains very encouraged by the three Ayombero wells drilled to date which have confirmed similar lithologies, oil saturations and over-pressure in the Galembo Member of the La Luna Carbonate reservoir, suggesting reservoir and structural continuity |
• | Vonu Este, PUT-1 (100% WI): On track to spud in fourth quarter 2019; the well's planned target is the A-Limestone. The Vonu-1 well has produced approximately 800,000 bbls of oil from the A-Limestone (from June 2017 to July 2019) and is still producing over 500 BOEPD; the Costayaco-19 well in the Chaza Block, has produced over 730,000 bbls of oil from the A-Limestone (from May 2016 to July 2019) |
• | 3D Seismic Program Update (341 Square Kilometers): seismic acquisition operations continue on the Alea 1848A, Nancy-Burdine-Maxine, PUT 4 and PUT 25 blocks; 30% of the seismic data has been recorded as of August 6, 2019, with the program expected to be fully recorded by September 30, 2019; this program is expected to be the largest seismic program ever conducted in the Putumayo Basin; interpretation is expected to begin during August 2019 and to continue as the data recording is completed |
• | LLA-10 (50% WI): Gran Tierra expects to participate in a non-operated exploration well (50% WI) in the LLA-10 Block in the second half of 2019; Gran Tierra's partner will pay 100% of the cost of the well |
• | LLA-85 (100% WI): the Company has been awarded this block following the recent ANH bid round; this block covers 136,400 acres within the Llanos Basin in Colombia, and is on trend with fields that produce medium to light crude oil from the Mirador, Une and Gacheta Formations; the block is currently 65% covered with 3D seismic and the Company has preliminarily identified four leads on the block |
• | VMM-24 Block (100% WI): the Company has also been awarded this block in the ANH bid round; the block covers 26,867 acres contiguous to Gran Tierra's core assets in the MMV Basin and is on-trend with the Colon, Juglar and Acordionero oil fields, which produce medium gravity crude oil from reservoirs such as the Umir, Lisama & La Paz sandstones intervals; this block is close to Gran Tierra's facilities and other existing infrastructure; the Company has preliminarily identified two leads on the block |
• | Gran Tierra officially signed participation contracts for three blocks located in Ecuador during the Quarter; the three blocks are located in the Oriente Basin and are approximately 140,000 acres in total area, creating a contiguous acreage position extending from Gran Tierra's existing assets in the Putumayo Basin in Colombia |
• | The Company is now one of the top landholders in the play trend which extends from the Putumayo Basin in Colombia through to the Oriente Basin in Ecuador; the Putumayo and Oriente Basins are the same geological basin, with different names due to the international border between Colombia and Ecuador |
Three Months Ended June 30, | Three Months Ended March, 31 | Six Months Ended June 30, | |||||||||||||||
2019 | 2018 | 2019 | 2019 | 2018 | |||||||||||||
Net Income | $ | 38,540 | $ | 20,300 | $ | 1,979 | $ | 40,519 | $ | 38,161 | |||||||
Per Share - Basic | $ | 0.10 | $ | 0.05 | $ | 0.01 | $ | 0.11 | $ | 0.10 | |||||||
Per Share - Diluted | $ | 0.10 | $ | 0.05 | $ | 0.01 | $ | 0.10 | $ | 0.10 | |||||||
Oil and Gas Sales | $ | 157,993 | $ | 163,446 | $ | 152,565 | $ | 310,558 | $ | 301,674 | |||||||
Operating Expenses | (33,733 | ) | (26,732 | ) | (34,783 | ) | (68,516 | ) | (48,508 | ) | |||||||
Workover Expenses | (12,757 | ) | (8,327 | ) | (6,289 | ) | (19,046 | ) | (12,816 | ) | |||||||
Transportation Expenses | (4,885 | ) | (6,522 | ) | (8,103 | ) | (12,988 | ) | (13,519 | ) | |||||||
Operating Netback(1) | $ | 106,618 | $ | 121,865 | $ | 103,390 | $ | 210,008 | $ | 226,831 | |||||||
G&A Expenses Before Stock-Based Compensation | $ | 9,268 | $ | 5,593 | $ | 7,869 | $ | 17,137 | $ | 13,575 | |||||||
G&A Stock-Based Compensation (Recovery) | (627 | ) | 6,609 | 1,727 | 1,100 | 9,787 | |||||||||||
G&A Expenses, Including Stock Based Compensation | $ | 8,641 | $ | 12,202 | $ | 9,596 | $ | 18,237 | $ | 23,362 | |||||||
EBITDA(1) | $ | 115,269 | $ | 102,278 | $ | 92,524 | $ | 207,793 | $ | 190,866 | |||||||
Funds Flow from Operations(1) | $ | 88,269 | $ | 94,549 | $ | 75,450 | $ | 163,719 | $ | 169,297 | |||||||
Capital Expenditures | $ | 99,595 | $ | 84,394 | $ | 94,489 | $ | 194,084 | $ | 157,088 | |||||||
Average Daily Volumes (BOEPD) | |||||||||||||||||
WI Production Before Royalties | 35,340 | 35,400 | 38,163 | 36,744 | 35,239 | ||||||||||||
Royalties | (6,147 | ) | (7,202 | ) | (6,499 | ) | (6,322 | ) | (7,045 | ) | |||||||
Production NAR | 29,193 | 28,198 | 31,664 | 30,422 | 28,194 | ||||||||||||
Decrease (Increase) in Inventory | 84 | (296 | ) | 169 | 127 | (639 | ) | ||||||||||
Sales | 29,277 | 27,902 | 31,833 | 30,549 | 27,555 | ||||||||||||
Royalties, % of WI Production Before Royalties | 17 | % | 20 | % | 17 | % | 17 | % | 20 | % | |||||||
Per BOE | |||||||||||||||||
Brent | $ | 68.32 | $ | 74.90 | $ | 63.90 | $ | 66.11 | $ | 71.04 | |||||||
Quality and Transportation Discount | (9.02 | ) | (10.52 | ) | (10.65 | ) | (9.95 | ) | (10.55 | ) | |||||||
Royalties | (10.38 | ) | (13.17 | ) | (8.99 | ) | (9.65 | ) | (12.21 | ) | |||||||
Average Realized Price | 48.92 | 51.21 | 44.26 | 46.51 | 48.28 | ||||||||||||
Transportation Expenses | (1.51 | ) | (2.04 | ) | (2.35 | ) | (1.95 | ) | (2.16 | ) | |||||||
Average Realized Price Net of Transportation Expenses | 47.41 | 49.17 | 41.91 | 44.56 | 46.12 | ||||||||||||
Operating Expenses | (10.44 | ) | (8.28 | ) | (10.09 | ) | (10.26 | ) | (7.69 | ) | |||||||
Workover Expenses | (3.95 | ) | (2.61 | ) | (1.82 | ) | (2.85 | ) | (2.05 | ) | |||||||
Operating Netback(1) | 33.02 | 38.28 | 30.00 | 31.45 | 36.38 | ||||||||||||
G&A Expenses | (2.87 | ) | (1.75 | ) | (2.28 | ) | (2.57 | ) | (2.17 | ) | |||||||
Severance Expenses | (0.08 | ) | (0.32 | ) | (0.19 | ) | (0.14 | ) | (0.16 | ) | |||||||
Realized Foreign Exchange (Loss) Gain | 0.31 | (0.11 | ) | (0.25 | ) | 0.02 | (0.07 | ) | |||||||||
Realized Financial Instruments Loss | (0.35 | ) | (3.03 | ) | (0.06 | ) | (0.20 | ) | (2.48 | ) | |||||||
Interest Expense, Excluding Amortization of Debt Issuance Costs | (2.98 | ) | (2.05 | ) | (2.06 | ) | (2.50 | ) | (1.82 | ) | |||||||
Interest Income | 0.12 | 0.19 | 0.04 | 0.08 | 0.22 | ||||||||||||
Current Income Tax Expense | 0.15 | (1.51 | ) | (3.30 | ) | (1.63 | ) | (2.74 | ) | ||||||||
Cash Netback(1) | $ | 27.32 | $ | 29.70 | $ | 21.90 | $ | 24.51 | $ | 27.16 | |||||||
Share Information (000s) | |||||||||||||||||
Common Stock Outstanding, End of Period | 376,636 | 390,018 | 384,493 | 376,636 | 390,018 | ||||||||||||
Exchangeable Shares Outstanding, End of Period | — | 1,135 | — | — | 1,135 | ||||||||||||
Weighted Average Number of Common and Exchangeable Shares Outstanding - Basic | 379,942 | 391,054 | 386,930 | 383,492 | 391,173 | ||||||||||||
Weighted Average Number of Common and Exchangeable Shares Outstanding - Diluted | 415,757 | 427,455 | 386,946 | 419,307 | 427,242 |
Three Months Ended June 30, | As at June 30, | As at March 31, | ||||||||||
Return on Average Capital Employed - (Non-GAAP) Measure ($000s) | 2019 | 2019 | 2019 | |||||||||
Net income | $ | 38,540 | ||||||||||
Adjustments to reconcile net income to EBIT: | ||||||||||||
Interest expense | 10,564 | |||||||||||
Income tax expense | 14,468 | |||||||||||
Earnings before interest and income tax | $ | 63,572 | ||||||||||
Total Assets | $ | 2,031,828 | $ | 1,824,748 | ||||||||
Less Current Liabilities | 189,186 | 197,201 | ||||||||||
Less Cash | 147,712 | 32,740 | ||||||||||
Capital Employed | $ | 1,694,930 | $ | 1,594,807 | ||||||||
Average Capital Employed | $ | 1,644,869 | ||||||||||
Annualized EBIT (multiplied by four) | $ | 254,288 | ||||||||||
Divided by Average Capital Employed | 1,644,869 | |||||||||||
Return on Average Capital Employed | 15.5 | % |
Three Months Ended June 30, | Six Months Ended June 30, | Three Months Ended March, 31 | ||||||||||||||||||
Cash Netback - (Non-GAAP) Measure ($000s) | 2019 | 2018 | 2019 | 2018 | 2019 | |||||||||||||||
Net income | $ | 38,540 | $ | 20,300 | $ | 40,519 | $ | 38,161 | $ | 1,979 | ||||||||||
Adjustments to reconcile net income to cash netback | ||||||||||||||||||||
DD&A expenses | 51,697 | 46,607 | 114,618 | 86,068 | 62,921 | |||||||||||||||
Deferred income tax expense | 14,957 | 23,169 | 23,280 | 36,651 | 8,323 | |||||||||||||||
Amortization of debt issuance costs | 947 | 843 | 1,785 | 1,513 | 838 | |||||||||||||||
Unrealized foreign exchange (gain) loss | 2,174 | 1,875 | (1,109 | ) | 831 | (3,283 | ) |
Non-cash operating expenses | — | 284 | — | 415 | — | |||||||||||||||
Non-cash G&A expense (recovery) | (627 | ) | 6,609 | 1,100 | 9,787 | 1,727 | ||||||||||||||
Unrealized financial instruments (gain) loss | (19,465 | ) | (4,898 | ) | (16,520 | ) | (3,769 | ) | 2,945 | |||||||||||
Cash netback | $ | 88,223 | $ | 94,789 | $ | 163,673 | $ | 169,657 | $ | 75,450 |
Three Months Ended June 30, | Six Months Ended June 30, | Three Months Ended March, 31 | ||||||||||||||||||
EBITDA - (Non-GAAP) Measure ($000s) | 2019 | 2018 | 2019 | 2018 | 2019 | |||||||||||||||
Net income | $ | 38,540 | $ | 20,300 | $ | 40,519 | $ | 38,161 | $ | 1,979 | ||||||||||
Adjustments to reconcile net income to EBITDA | ||||||||||||||||||||
DD&A expenses | 51,697 | 46,607 | 114,618 | 86,068 | 62,921 | |||||||||||||||
Interest expense | 10,564 | 7,375 | 18,502 | 12,870 | 7,938 | |||||||||||||||
Income tax expense | 14,468 | 27,996 | 34,154 | 53,767 | 19,686 | |||||||||||||||
EBITDA | $ | 115,269 | $ | 102,278 | $ | 207,793 | $ | 190,866 | $ | 92,524 |
Three Months Ended June 30, | Six Months Ended June 30, | Three Months Ended March, 31 | ||||||||||||||||||
Funds Flow From Operations - (Non-GAAP) Measure ($000s) | 2019 | 2018 | 2019 | 2018 | 2019 | |||||||||||||||
Net income | $ | 38,540 | $ | 20,300 | $ | 40,519 | $ | 38,161 | $ | 1,979 | ||||||||||
Adjustments to reconcile net income to funds flow from operations | ||||||||||||||||||||
DD&A expenses | 51,697 | 46,607 | 114,618 | 86,068 | 62,921 | |||||||||||||||
Deferred tax expense | 14,957 | 23,169 | 23,280 | 36,651 | 8,323 | |||||||||||||||
Stock-based compensation expense (recovery) | (627 | ) | 6,893 | 1,100 | 10,202 | 1,727 | ||||||||||||||
Amortization of debt issuance costs | 947 | 843 | 1,785 | 1,513 | 838 | |||||||||||||||
Cash settlement of RSUs | — | (240 | ) | — | (360 | ) | — | |||||||||||||
Non-cash lease expense | 894 | — | 894 | — | — | |||||||||||||||
Lease payments | (848 | ) | — | (848 | ) | — | — | |||||||||||||
Unrealized foreign exchange (gain) loss | 2,174 | 1,875 | (1,109 | ) | 831 | (3,283 | ) | |||||||||||||
Financial instruments loss | (18,340 | ) | 4,768 | (15,175 | ) | 11,714 | 3,165 | |||||||||||||
Cash settlement of financial instruments | (1,125 | ) | (9,666 | ) | (1,345 | ) | (15,483 | ) | (220 | ) | ||||||||||
Funds flow from operations | $ | 88,269 | $ | 94,549 | $ | 163,719 | $ | 169,297 | $ | 75,450 |
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