# EDGAR Filing Document

**Accession Number:** 0001273441
**File Stem:** 0001104659-23-006535
**Filing Date:** 2023-1
**Character Count:** 62495
**Document Hash:** 02284978e5299c683dfb2505772ad4c3
**Contains OCR:** False
**Source Format:** 

## Filing Content

## Filing Summary
**0001104659-23-006535.hdr.sgml**: 20230125

**ACCESSION NUMBER**: 0001104659-23-006535

**CONFORMED SUBMISSION TYPE**: 8-K

**PUBLIC DOCUMENT COUNT**: 14

**CONFORMED PERIOD OF REPORT**: 20230124

**ITEM INFORMATION**: Results of Operations and Financial Condition

**ITEM INFORMATION**: Financial Statements and Exhibits

**FILED AS OF DATE**: 20230125

**DATE AS OF CHANGE**: 20230125

**FILER**: 

**COMPANY DATA:**
- **COMPANY CONFORMED NAME:** GRAN TIERRA ENERGY INC.
- **CENTRAL INDEX KEY:** 0001273441
- **STANDARD INDUSTRIAL CLASSIFICATION:** CRUDE PETROLEUM & NATURAL GAS [1311]
- **IRS NUMBER:** 000000000
- **STATE OF INCORPORATION:** DE
- **FISCAL YEAR END:** 1231

**FILING VALUES:**
- **FORM TYPE:** 8-K
- **SEC ACT:** 1934 Act
- **SEC FILE NUMBER:** 001-34018
- **FILM NUMBER:** 23552583

**BUSINESS ADDRESS:**
- **STREET 1:** 500 CENTRE STREET SE
- **CITY:** CALGARY
- **STATE:** A0
- **ZIP:** T2G 1A6
- **BUSINESS PHONE:** (403) 265-3221

**MAIL ADDRESS:**
- **STREET 1:** 500 CENTRE STREET SE
- **CITY:** CALGARY
- **STATE:** A0
- **ZIP:** T2G 1A6

**FORMER COMPANY:**
- **FORMER CONFORMED NAME:** GRAN TIERRA ENERGY, INC.
- **DATE OF NAME CHANGE:** 20051130

**FORMER COMPANY:**
- **FORMER CONFORMED NAME:** GOLDSTRIKE INC
- **DATE OF NAME CHANGE:** 20040113

**FORMER COMPANY:**
- **FORMER CONFORMED NAME:** GOLKSTRIKE INC
- **DATE OF NAME CHANGE:** 20031216

?xml version="1.0" encoding="utf-8"?

**UNITED STATES**

**SECURITIES AND EXCHANGE COMMISSION**

**Washington, D.C. 20549**

**FORM 8-K** 

**CURRENT REPORT**

**Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934**

**Date of Report (Date of earliest event reported): January 24, 2023** 

**<u>GRAN TIERRA ENERGY INC.</u>**

**(Exact name of Registrant as specified in its charter)**

---

| | |
|:---|:---|
| **Delaware** | **98-0479924** |
| **(State or other jurisdiction of incorporation)** | **(I.R.S. Employer Identification No.)** |

---

**Commission file number: <u>001-34018</u>**

 **500 Centre Street S.E.**

**Calgary, Alberta Canada T2G 1A6**

**(Address of principal executive offices and zip code)**

**Registrant's telephone number, including area code:** (403) 265-3221

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):

◻ Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

◻ Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

◻ Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

◻ Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Securities registered pursuant to Section 12(b) of the Act:

---

| | | |
|:---|:---|:---|
| Title of each class | Trading Symbol(s) | Name of each exchange on which registered |
| Common Stock, par value $0.001 per share | GTE | NYSE American |
|  |  | Toronto Stock Exchange |
|  |  | London Stock Exchange |

---

Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).

Emerging growth company ◻

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ◻

**Item 2.02. Results of Operations and Financial Condition.**

On January 24, 2023, the Company issued a press release anouncing its 2022 year-end reserves. A copy of the press release is attached hereto as Exhibit 99.1 and incorporated by reference herein in its entirety.

The information in this Item 2.02 and in Exhibit 99.1 attached to this report is being furnished and shall not be deemed "filed" for the purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the "Exchange Act"), or otherwise subject to the liabilities of that section, nor shall it be deemed to be incorporated by reference into any filing by the Company under the Securities Act of 1933, as amended, or the Exchange Act, regardless of any general incorporation language contained in such filing.

**Item 9.01. Financial Statements and Exhibits.**

(d) Exhibits.

---

| | |
|:---|:---|
| **Exhibit <br> Number** | **Description** |
| [99.1](tm234212d1_ex99-1.htm) | [Press Release issued on January 24, 2023.](tm234212d1_ex99-1.htm) |
| 104 | Cover Page Interactive Data File - the cover page XBRL tags are embedded within the Inline XBRL document. |

---

**SIGNATURE**

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

---

| | |
|:---|:---|
| January 25, 2023 | &nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;GRAN TIERRA ENERGY INC. |
|  | /s/ Ryan Ellson |
|  | By: Ryan Ellson |
|  | Executive Vice President and Chief Financial Officer |

---

## Exhibit 99.1

**Exhibit 99.1**

![](tm234212d1_ex99-1img01.jpg)

**Gran Tierra Energy Inc. Announces Strong Reserves Replacement and Continued Reserves Growth in 2022**

•  ***Added Total Company Reserves of 14 MMBOE 1P, 17 MMBOE 2P and 31 MMBOE 3P*** 

•  ***Achieved 126% 1P, 148% 2P and 280% 3P Reserves Replacement*** 

•  ***Fourth Consecutive Year of 1P Reserves Growth*** 

•  ***Exploration Discoveries Alone Added Company Reserves of 5 MMBOE 1P, 16 MMBOE 2P and 32 MMBOE 3P*** 

•  ***Achieved Three-Year Average Per Barrel Finding and Development Costs of $11.69 PDP and $14.51 1P*** 

•  ***Reserve Life Indexes of 7 (1P), 11 (2P) and 15 (3P) Years*** 

•  ***Net Present Value Before Tax Discounted at 10 Percent Increased to $2.1 Billion (1P), $3.0 Billion (2P) and $4.1 Billion (3P)*** 

•  ***1P Net Asset Value per Share of $4.62 Before Tax, Up 77% from 2021*** 

•  ***2P Net Asset Value per Share of $7.36 Before Tax, Up 56% from 2021*** 

•  ***Net Debt-Adjusted Production per Share Growth of 67% since 2021*** 

•  ***Net Debt-Adjusted Reserves per Share Growth of 56% (1P), 57% (2P) and 69% (3P) since 2021*** 

•  ***Future Net Revenue After Taxes and Capital Expenditures Forecast to be $1.4 Billion (1P), $1.7 Billion (2P) and $1.9 Billion (3P) Over the Next Five Years*** 

•  ***Strong Start to 2023 with Year-to-Date Total Company Average Production of Approximately 33,000 BOPD*** 

**CALGARY, Alberta – January 24, 2023 –** Gran Tierra Energy Inc. ("**Gran Tierra"** or the "**Company**") **(NYSE American:GTE)(NYSE MKT:GTE)(TSX:GTE)(LSE:GTE)**, a company focused on international oil exploration and production with assets currently in Colombia and Ecuador, today announced the Company's 2022 year-end reserves as evaluated by the Company's independent qualified reserves evaluator McDaniel & Associates Consultants Ltd. ("**McDaniel"**) in a report with an effective date of December 31, 2022 (the "**GTE McDaniel Reserves Report"**).

All dollar amounts are in United States ("**U.S.**") dollars and all reserves and production volumes are on a working interest before royalties (**"WI"**) basis. Production is expressed in barrels (**"bbl"**) of oil per day (**"bopd"**), while reserves are expressed in bbl, bbl of oil equivalent (**"boe"**) or million boe (**"MMBOE"**), unless otherwise indicated. All reserves values, future net revenue and ancillary information contained in this press release have been prepared by McDaniel and calculated in compliance with Canadian National Instrument 51-101 – *Standards of Disclosure for Oil and Gas Activities* ("**NI 51-101**") and the Canadian Oil and Gas Evaluation Handbook ("**COGEH"**) and derived from the GTE McDaniel Reserves Report, unless otherwise expressly stated. The following reserves categories are discussed in this press release: Proved Developed Producing (**"PDP"**), Proved (**"1P"**), 1P plus Probable (**"2P"**) and 2P plus Possible (**"3P"**).

Gary Guidry, President and Chief Executive Officer of Gran Tierra, commented: "During 2022, Gran Tierra achieved strong 126% (1P), 148% (2P) and 280% (3P) reserves replacement through our successful results from our development and exploration drilling, waterflooding programs and field performance. We completed our 2022 development plan on-budget including waterflooding efforts and development drilling in the Acordionero, Costayaco and Moqueta oil fields. After reduced exploration activity during 2020 and 2021, the Company also made several key exploration discoveries during 2022. We believe our success on multiple fronts during 2022 demonstrates Gran Tierra's ability to be a full-cycle oil and gas exploration, development and production company focused on value creation for all our stakeholders.

The success the Company achieved in 2022 also reflects our ongoing conversion of reserves from the Probable to the Proved category. With 115 booked Proved plus Probable Undeveloped future drilling locations, Gran Tierra is well positioned to continue to grow the Company's production in 2023 and beyond.

During 2022, a combination of our ongoing reductions in debt and per well drilling, completion and workover costs, focus on maintaining low operating costs, strong rebound in oil prices and share buybacks allowed Gran Tierra to achieve net asset values per share<sup>\*</sup> before tax of $4.62 (1P), up 77% from 2021, and $7.36 (2P), up 56% from 2021. With this significant growth in our net asset values per share<sup>\*</sup> in 2022, we believe Gran Tierra is well positioned to offer exceptional long-term stakeholder value.

We have started 2023 strong with year-to-date average production of approximately 33,000 bopd, which is the midpoint of our 2023 production guidance. We also recently drilled the Moqueta-25 development well, which we expect to bring on production in the new few weeks. We have secured two drilling rigs for our 2023 Acordionero and Costayaco development drilling programs and expect to spud development wells in both fields in early February 2023. We also plan to continue to focus on the development of our existing assets, appraisal of new discoveries and new exploration drilling, while generating free cash flow to strengthen our balance sheet and return capital to shareholders through share buybacks."

**Highlights**

**2022 Year-End Reserves and Values**

---

| | | | | |
|:---|:---|:---|:---|:---|
| **Before Tax (as of December 31, 2022)** | **Units** | **1P** | **2P** | **3P** |
| **Reserves** | **MMBOE** | 84 | 130 | 183 |
| **Net Present Value at 10% Discount ("NPV10")** | **$ million** | 2053 | 2999 | 4075 |
| **Net Debt<sup>1</sup>** | **$ million** | (453) | (453) | (453) |
| **Net Asset Value (NPV10 less Net Debt) ("NAV")** | **$ million** | 1600 | 2546 | 3622 |
| **Outstanding Shares<sup>2</sup>** | **million** | 346 | 346 | 346 |
| **NAV per Share** | **$/share** | 4.62 | 7.36 | 10.47 |
| **NAV per Share Change from December 31, 2021** | **%** | 77% | 56% | 59% |

---

---

| | | | | |
|:---|:---|:---|:---|:---|
| **After Tax (as of December 31, 2022)** | **Units** | **1P** | **2P** | **3P** |
| **Reserves** | **MMBOE** | 84 | 130 | 183 |
| **NPV10** | **$ million** | 1328 | 1833 | 2409 |
| **Net Debt<sup>1</sup>** | **$ million** | (453) | (453) | (453) |
| **NAV** | **$ million** | 875 | 1380 | 1956 |
| **Outstanding Shares<sup>2</sup>** | **million** | 346 | 346 | 346 |
| **NAV per Share** | **$/share** | 2.53 | 3.99 | 5.65 |
| **NAV per Share Change from December 31, 2021** | **%** | 59% | 37% | 38% |

---

\*See the above tables for the definitions of net asset values per share.

• During
 2022, Gran Tierra achieved:

&nbsp;&nbsp;&nbsp;&nbsp;◦ Material
 growth in its 2022 year-end 1P NPV10 before tax valuation, which increased by 26% compared
 to 2021 year-end, and 2022 year-end 2P NPV10 before tax valuation, which increased by 25%
 compared to 2021 year-end, driven by the Company's successful development and exploration
 programs and a strong recovery in oil prices.

&nbsp;&nbsp;&nbsp;&nbsp;◦ Growth
 in the Company's 2022 year-end 1P NPV10 and 2P NPV10 after tax valuations of 6% and 5% respectively,
 compared to 2021 year-end, which incorporated the new Colombian tax regime. The new Colombian
 tax regime lowered the Company's NPV10 after tax in all reserves categories by approximately
 8% to 12% relative to the previous tax regime.

&nbsp;&nbsp;&nbsp;&nbsp;◦ Strong
 reserves replacement ratios of:

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;▪ 126% 1P, with 1P reserves additions of 14 MMBOE (38% attributable
 to exploration discoveries).

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;▪ 148% 2P, with 2P reserves additions of 17 MMBOE (95% attributable
 to exploration discoveries).

&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;▪ 280% 3P, with 3P reserves additions of 31 MMBOE (103% attributable
 to exploration discoveries).

&nbsp;&nbsp;&nbsp;&nbsp;◦ Material
 1P reserves additions largely driven by success with development drilling and waterflooding
 results at Acordionero and Costayaco, in addition to several exploration discoveries.

&nbsp;&nbsp;&nbsp;&nbsp;◦ Material
 2P and 3P reserve additions through the success of the Company's 2022 exploration program,
 which made several discoveries.

&nbsp;&nbsp;&nbsp;&nbsp;◦ Finding
 and development costs (**"F&D"**), including change in future development
 costs (**"FDC"**), on a per boe basis of $18.18 (1P), $20.08 (2P) and $12.20
 (3P).

&nbsp;&nbsp;&nbsp;&nbsp;◦ Three-year
 average F&D, including change in FDC, on a per boe basis of $11.69 (PDP) and $14.51 (1P).

&nbsp;&nbsp;&nbsp;&nbsp;◦ F&D
 recycle ratios\*, including change in FDC, of 2.1 times (1P), 1.9 times (2P) and 3.2 times
 (3P).

&nbsp;&nbsp;&nbsp;&nbsp;◦ Net
 debt-adjusted production per share<sup>3</sup> growth of 67% since 2021.

&nbsp;&nbsp;&nbsp;&nbsp;◦ Net
 debt-adjusted reserves per share<sup>4</sup> growth of 56% (1P), 57% (2P) and 69% (3P) since
 2021.

&nbsp;&nbsp;&nbsp;&nbsp;◦ Significant
 reserves additions at Acordionero: 6 MMBOE (PDP) and 8 MMBOE (1P).

&nbsp;&nbsp;&nbsp;&nbsp;◦ Material
 reserves additions from exploration discoveries: 5 MMBOE (1P), 16 MMBOE (2P) and 32 MMBOE
 (3P).

• Gran Tierra's
 four major oil assets, Acordionero, Costayaco, Moqueta and Suroriente (all on waterflood)
 represent 81% of the Company's 1P reserves and 68% of its 2P reserves.

• The Company
 is benefiting from ongoing material cost reductions for development drilling, completions
 and workovers in the Acordionero oil field, Gran Tierra's largest oil asset:

&nbsp;&nbsp;&nbsp;&nbsp;◦ The
 Company drilled 22 development wells in Acordionero during 2022.

&nbsp;&nbsp;&nbsp;&nbsp;◦ These
 new wells were drilled for an average cost of approximately $1.1 million per well, a reduction
 of 47% from the average for 2019.

&nbsp;&nbsp;&nbsp;&nbsp;◦ These
 new wells' completion costs averaged approximately $0.7 million per well, a reduction of
 41% from the average for 2019.

&nbsp;&nbsp;&nbsp;&nbsp;◦ The
 average 2022 workover cost of an existing well was $0.4 million per well, down 51% from the
 2019 average.

• PDP reserves
 account for 56% of 1P reserves and 1P reserves account for 64% of 2P reserves, demonstrating
 strength of the Company's reserves base via the potential future conversion of Probable reserves
 into 1P reserves and Proved Undeveloped reserves into PDP reserves.

• Gran
 Tierra's mature waterflood assets, Costayaco and Moqueta, continued to grow and deliver value,
 with total 2022 reserves additions of 2 MMBOE (2P) and 1 MMBOE (2P), respectively.

• FDC
 are forecast to be $403 million for 1P reserves
 and $677 million for 2P reserves. Gran Tierra's
 2023 base case mid-point guidance for cash flow\*\* of $295 million is equivalent to 73% of
 1P FDC and 44% of 2P FDC, which highlights the Company's potential ability to fund future
 development capital. Increases in FDC relative to 2021 reflect that McDaniel has now recognized
 that Gran Tierra has 78 Proved Undeveloped future drilling locations (up from 61 in 2021) and 115 Proved plus Probable Undeveloped future drilling locations (up from
 94 in 2021).

**2023 Production**

• Gran Tierra's
 2023 year-to-date total average Company production is off to a strong start with an approximate
 average of 33,000 bopd<sup>5</sup>, within the Company's 2023 guidance range of 32,000-34,000
 bopd.

\*F&D recycle ratio is defined as fourth quarter 2022 operating netback per WI sales volume boe divided by the appropriate F&D costs on a per boe basis. Operating netback does not have a standardized meaning under generally accepted accounting principles in the United States of America (**"GAAP"**) and is a non-GAAP measure. Operating netback is defined as oil sales less operating and transportation expenses. See "Non-GAAP Measures" in this press release.

\*\* "Cash flow" refers to GAAP line item "net cash provide by operating activities". Gran Tierra's 2023 base case guidance is based on a forecast 2023 average Brent oil price of $85/bbl.

**Future Net Revenue**

Future net revenue reflects McDaniel's forecast of revenue estimated using forecast prices and costs, arising from the anticipated development and production of reserves, after the deduction of royalties, operating costs, development costs, abandonment and reclamation costs and taxes but before consideration of indirect costs such as administrative, overhead and other miscellaneous expenses. The estimate of future net revenue below does not necessarily represent fair market value.

**Consolidated Properties at December 31, 2022**

**Proved (1P) Total Future Net Revenue ($ million)**

**Forecast Prices and Costs**

---

| | | | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|:---|:---|
|  | **Sales<br> Revenue** | **Total<br> Royalties** | **Operating<br> Costs** | **Future<br> Development<br> Capital** | **Abandonment<br> and <br> Reclamation <br> Costs** | **Future Net<br> Revenue<br> Before <br> Future <br> Taxes** | **Future<br> Taxes** | **Future<br> Net <br> Revenue<br> After<br> Future Taxes\*** |
| 2023-2027 <br> (5 Years) | 4074 | (840) | (782) | (403) | (2) | 2047 | (677) | 1370 |
| Remainder | 1850 | (335) | (662) |  | (63) | 790 | (321) | 469 |
| Total (Undiscounted) | 5924 | (1175) | (1444) | (403) | (65) | 2837 | (998) | 1839 |
| Total (Discounted @ 10%) | 4225 | (853) | (943) | (353) | (23) | 2053 | (725) | 1328 |

---

**Consolidated Properties at December 31, 2022**

**Proved Plus Probable (2P) Total Future Net Revenue ($ million)**

**Forecast Prices and Costs**

---

| | | | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|:---|:---|
| **Years** | **Sales<br> Revenue** | **Total<br> Royalties** | **Operating<br> Costs** | **Future<br> Development<br> Capital** | **Abandonment<br> and<br> Reclamation<br> Costs** | **Future Net<br> Revenue<br> Before<br> Future <br> Taxes** | **Future <br> Taxes** | **Future<br> Net <br> Revenue<br> After <br> Future<br> Taxes\*** |
| 2023-2027 <br> (5 Years) | 5357 | (1119) | (908) | (677) | (2) | 2651 | (994) | 1657 |
| Remainder | 3958 | (780) | (1204) |  | (82) | 1892 | (782) | 1110 |
| Total (Undiscounted) | 9315 | (1899) | (2112) | (677) | (84) | 4543 | (1776) | 2767 |
| Total (Discounted @ 10%) | 6078 | (1252) | (1238) | (566) | (23) | 2999 | (1166) | 1833 |

---

**Consolidated Properties at December 31, 2022**

**Proved Plus Probable Plus Possible (3P) Total Future Net Revenue ($ million)**

**Forecast Prices and Costs**

---

| | | | | | | | | |
|:---|:---|:---|:---|:---|:---|:---|:---|:---|
| **Years** | **Sales <br> Revenue** | **Total <br> Royalties** | **Operating <br> Costs** | **Future <br> Development <br> Capital** | **Abandonment <br> and <br> Reclamation<br> Costs** | **Future Net <br> Revenue <br> Before <br> Future <br> Taxes** | **Future <br> Taxes** | **Future <br> Net <br> Revenue<br> After <br> Future <br> Taxes\*** |
| 2023-2027 <br> (5 Years) | 6428 | (1355) | (1008) | (854) | (2) | 3209 | (1284) | 1925 |
| Remainder | 6876 | (1474) | (1825) |  | (93) | 3484 | (1495) | 1989 |
| Total (Undiscounted) | 13304 | (2829) | (2833) | (854) | (95) | 6693 | (2779) | 3914 |
| Total (Discounted @ 10%) | 7988 | (1692) | (1503) | (696) | (22) | 4075 | (1666) | 2409 |

---

\*The after-tax net present value of the Company's oil and gas properties reflects the tax burden on the properties on a stand-alone basis. It does not consider the corporate tax situation, or tax planning. It does not provide an estimate of the value at the Company level which may be significantly different. The Company's financial statements, when available for the year ended December 31, 2022, should be consulted for information at the Company level.

**Total Company WI Reserves**

The following table summarizes Gran Tierra's NI 51-101 and COGEH compliant reserves in Colombia and Ecuador derived from the GTE McDaniel Reserves Report calculated using forecast oil and gas prices and costs. Gran Tierra has determined that Ecuador reserves, included in the Total Proved, Total Probable and Total Possible reserve categories for Light and Medium Crude Oil, are not material enough to present separately on a country basis. Therefore all amounts are presented on a consolidated basis by foreign geographic area.

---

| | | | | |
|:---|:---|:---|:---|:---|
| | **Light and <br> Medium <br> Crude Oil** | **Heavy Crude <br> Oil** | **Conventional<br> Natural Gas** | **2022 Year-<br> End** |
| <br>*Reserves Category* | **Mbbl\*** | **Mbbl\*** | **MMcf\*\*** | **Mboe\*\*\*** |
| Proved Developed Producing | **23737** | **23261** | **883** | **47145** |
| Proved Developed Non-Producing | **2713** | **715** | **—** | **3428** |
| Proved Undeveloped | **15831** | **17183** | **662** | **33124** |
| **Total Proved** | **42281** | **41159** | **1545** | **83697** |
| Total Probable | **25781** | **20589** | **352** | **46430** |
| **Total Proved plus Probable** | **68062** | **61748** | **1897** | **130127** |
| Total Possible | **27157** | **25309** | **357** | **52525** |
| **Total Proved plus Probable plus Possible** | **95219** | **87057** | **2254** | **182652** |

---

\*Mbbl (thousand bbl of oil).

\*\*MMcf (million cubic feet).

\*\*\*MBOE (thousand boe).

**Net Present Value Summary**

Gran Tierra's reserves were evaluated using McDaniel's commodity price forecasts at January 1, 2023. It should not be assumed that the net present value of cash flow estimated by McDaniel represents the fair market value of the reserves.

---

| | | | | | |
|:---|:---|:---|:---|:---|:---|
| **Total Company** | **Discount Rate** | **Discount Rate** | **Discount Rate** | **Discount Rate** | **Discount Rate** |
| **($ millions)** | **0%** | **5%** | **10%** | **15%** | **20%** |
| ***Before tax*** |  |  |  |  |  |
| Proved Developed Producing | **1670** | **1475** | **1324** | **1204** | **1108** |
| Proved Developed Non-Producing | **122** | **101** | **85** | **73** | **63** |
| Proved Undeveloped | **1044** | **812** | **644** | **519** | **424** |
| Total Proved | **2836** | **2388** | **2053** | **1796** | **1595** |
| Total Probable | **1707** | **1250** | **946** | **738** | **589** |
| Total Proved plus Probable | **4543** | **3638** | **2999** | **2534** | **2184** |
| Total Possible | **2150** | **1483** | **1076** | **813** | **635** |
| Total Proved plus Probable plus Possible | **6693** | **5121** | **4075** | **3347** | **2819** |
| ***After tax*** |  |  |  |  |  |
| Proved Developed Producing | **1170** | **1039** | **934** | **850** | **781** |
| Proved Developed Non-Producing | **72** | **58** | **49** | **41** | **35** |
| Proved Undeveloped | **596** | **451** | **345** | **266** | **205** |
| Total Proved | **1838** | **1548** | **1328** | **1157** | **1021** |
| Total Probable | **929** | **677** | **505** | **386** | **302** |
| Total Proved plus Probable | **2767** | **2225** | **1833** | **1543** | **1323** |
| Total Possible | **1147** | **796** | **576** | **433** | **335** |
| Total Proved plus Probable plus Possible | **3914** | **3021** | **2409** | **1976** | **1658** |

---

**Total Company WI Reserves Reconciliation**

---

| | | | |
|:---|:---|:---|:---|
|  | **Proved** | **Proved plus Probable** | **Proved plus Probable plus<br> Possible** |
|  | **MBOE** | **MBOE** | **MBOE** |
| December 31, 2021 | 80816 | 124692 | 162485 |
| Extensions | 7612 | 9237 | 16162 |
| Technical Revisions | 4433 | 1326 | (44) |
| Discoveries | 1674 | 5573 | 14855 |
| Economic Factors | 384 | 521 | 416 |
| Production | (11222) | (11222) | (11222) |
| **December 31, 2022** | **83697** | **130127** | **182652** |

---

**Reserve Life Index (Years)**

---

| | |
|:---|:---|
|  | **December 31, 2022\*** |
| **Total Proved** | **7** |
| **Total Proved plus Probable** | **11** |
| **Total Proved plus Probable plus Possible** | **15** |

---

\* Calculated using average fourth quarter 2022 WI production of 32,595 bopd.

**Future Development Costs**

FDC reflects McDaniel's best estimate of what it will cost to bring the Proved Undeveloped and Probable reserves on production. Changes in forecast FDC occur annually as a result of development activities, acquisition and disposition activities, and changes in capital cost estimates based on improvements in well design and performance, as well as changes in service costs. FDC for 2P reserves increased to $677 million at year-end 2022 from $578 million at year-end 2021. The increase in FDC in 2022 was predominantly attributed to the increase in the numbers of future development well locations identified by McDaniel in the Acordionero field as well as new locations identified during exploration drilling.

---

| | | | |
|:---|:---|:---|:---|
| **($ millions)** | **Total Proved** | **Total Proved Plus Probable** | **Total Proved Plus Probable <br> Plus Possible** |
| 2023 | 157 | 164 | 169 |
| 2024 | 102 | 144 | 155 |
| 2025 | 116 | 224 | 258 |
| 2026 | 28 | 117 | 191 |
| 2027 |  | 28 | 81 |
| Remainder |  |  |  |
| Total (undiscounted) | 403 | 677 | 854 |

---

---

| | | | |
|:---|:---|:---|:---|
| **($) millions** | **Proved** | **Proved plus<br> Probable** | **Proved plus<br> Probable plus<br> Possible** |
| Acordionero | 154 | 154 | 154 |
| Chaza Block (Costayaco & Moqueta) | 96 | 132 | 139 |
| Other | 153 | 391 | 561 |
| Total FDC Costs (undiscounted) | **403** | **677** | **854** |

---

**** 

**Finding and Development Costs** 

---

| | |
|:---|:---|
| **Reserves (MBOE)** | **Year Ended December 31, 2022** |
| Proved Developed Producing | 47145 |
| Total Proved | 83697 |
| Total Proved plus Probable | 130127 |
| Total Proved plus Probable plus Possible | 182652 |
| **Capital Expenditures ($000s)** |  |
| - including and excluding acquired properties | 236183 |
| **Operating Netback\* ($/bbl, per WI sales volumes)** |  |
| Operating Netback\* - fourth quarter 2022 | 38.72 |

---

\*Operating Netback is a Non-GAAP measure and does not have a standardized meaning under GAAP. Operating netback as presented is defined as oil sales less operating and transportation expenses. See "Non-GAAP Measures" in this press release.

**Finding and Development Costs, Excluding FDC<sup>\*</sup>**

**** 

---

| | |
|:---|:---|
|  | **Year Ended December 31, 2022** |
| **Proved Developed Producing** |  |
| Reserve Additions (MBOE) | 10705 |
| F&D Costs ($/BOE) | 22.06 |
| F&D Recycle Ratio | 1.8 |

---

**Finding and Development Costs, Including FDC<sup>\*</sup>**

**** 

---

| | |
|:---|:---|
|  | **Year Ended December 31, 2022** |
| **Proved Developed Producing** |  |
| Change in FDC ($000s) | (6735) |
| Reserve Additions (MBOE) | 10705 |
| F&D Costs ($/BOE) | 21.43 |
| F&D Recycle Ratio | 1.8 |

---

**Finding and Development Costs , Excluding FDC<sup>\*</sup>**

---

| | |
|:---|:---|
|  | **Year Ended December 31, 2022** |
| **Total Proved** |  |
| Reserve Additions (MBOE) | 14103 |
| F&D Costs ($/BOE) | 16.75 |
| F&D Recycle Ratio | 2.3 |

---

**Finding and Development Costs , Including FDC<sup>\*</sup>**

---

| | |
|:---|:---|
|  | **Year Ended December 31, 2022** |
| **Total Proved** |  |
| Change in FDC ($000s) | 20201 |
| Reserve Additions (MBOE) | 14103 |
| F&D Costs ($/BOE) | 18.18 |
| F&D Recycle Ratio | 2.1 |

---

**Finding and Development Costs , Excluding FDC<sup>\*</sup>**

---

| | |
|:---|:---|
|  | **Year Ended December 31, 2022** |
| **Total Proved plus Probable** |  |
| Reserve Additions (MBOE) | 16657 |
| F&D Costs ($/BOE) | 14.18 |
| F&D Recycle Ratio | 2.7 |

---

**Finding and Development Costs , Including FDC<sup>\*</sup>**

**** 

---

| | |
|:---|:---|
|  | **Year Ended December 31, 2022** |
| **Total Proved plus Probable** |  |
| Change in FDC ($000s) | 98342 |
| Reserve Additions (MBOE) | 16657 |
| F&D Costs ($/BOE) | 20.08 |
| F&D Recycle Ratio | 1.9 |

---

**Finding and Development Costs , Excluding FDC<sup>\*</sup>**

---

| | |
|:---|:---|
|  | **Year Ended December 31, 2022** |
| **Total Proved plus Probable plus Possible** |  |
| Reserve Additions (MBOE) | 31389 |
| F&D Costs ($/BOE) | 7.52 |
| F&D Recycle Ratio | 5.1 |

---

**Finding and Development Costs , Including FDC<sup>\*</sup>**

**** 

---

| | |
|:---|:---|
|  | **Year Ended December 31, 2022** |
| **Total Proved plus Probable plus Possible** |  |
| Change in FDC ($000s) | 146738 |
| Reserve Additions (MBOE) | 31389 |
| F&D Costs ($/BOE) | 12.20 |
| F&D Recycle Ratio | 3.2 |

---

\*In all cases, the F&D number is calculated by dividing the identified capital expenditures by the applicable reserves additions both before and after changes in FDC costs. Both F&D costs take into account reserves revisions during the year on a per BOE basis. F&D recycle ratio is defined as fourth quarter 2022 operating netback per working interest sales volume BOE divided by the appropriate F&D costs on a per BOE basis. The aggregate of the exploration and development costs incurred in the financial year and the changes during that year in estimated future development costs may not reflect the total F&D costs related to reserves additions for that year. Operating Netback is a Non-GAAP measure and does not have a standardized meaning under GAAP. Operating netback is defined as oil sales less operating and transportation expenses. See "Non-GAAP Measures" in this press release.

**Forecast prices**

The pricing assumptions used in estimating NI 51-101 and COGEH compliant reserves data disclosed above with respect to net present values of future net revenue are set forth below. The price forecasts are based on McDaniel's standard price forecast effective January 1, 2023. McDaniel is an independent qualified reserves evaluator and auditor pursuant to NI 51-101.

---

| | | |
|:---|:---|:---|
|  | **Brent Crude Oil**<br>**$US/bbl** | **WTI Crude Oil**<br>**$US/bbl** |
| **Year** | **January 1, 2023** | **January 1, 2023** |
| 2023 | **$84.00** | **$80.00** |
| 2024 | **$80.58** | **$76.50** |
| 2025 | **$79.59** | **$75.43** |
| 2026 | **$78.53** | **$74.28** |
| 2027 | **$80.10** | **$75.77** |

---

<sup>1</sup> Based on estimated year-end 2022 net debt of $453 million comprised of Senior Notes of $580 million (gross) less cash and cash equivalents of $127 million, prepared in accordance with GAAP.

<sup>2</sup> Outstanding Shares – Total shares issued less shares repurchased but not yet cancelled.

<sup>3</sup>Net debt adjusted production is calculated by dividing (x) fourth quarter WI production by (y) the sum of (a) the year-end net debt by the closing price of the Company's common shares on the New York Stock Exchange at year-end and (b) the Company's outstanding shares at year-end. Debt adjusted reserves is calculated by dividing (x) year-end reserves by (y) the sum of (a) the unaudited year-end net debt by the closing price of the Company's common shares on the New York Stock Exchange at year-end and (b) the Company's outstanding shares at year-end.

For 2022, the Company had unaudited year-end net debt of $453 million, a closing price on the New York Stock Exchange at December 31, 2022 of $0.99/share and 346,151,157 shares outstanding. Fourth quarter WI production was 32,595 bopd, 1P reserves were 83,697 MMBOE, 2P were 130,127 MMBOE and 3P were 182,652 MMBOE.

For 2021, the Company had audited year-end net debt of $641 million (comprised of gross amount of senior notes of $600 million, gross amount of reserves-based credit facility of $67.5 million and cash of $26 million), a closing price on the New York Stock Exchange at December 31, 2021 of $0.76/share and 367,144,500 shares outstanding. Fourth quarter WI production was 29,493 bopd, 1P reserves were 80,816 MMBOE, 2P were 124,692 MMBOE, and 3P were 162,485 MMBOE.

<sup>4</sup>Net debt adjusted production and reserves per share are non-GAAP financial ratios that are not a standardized financial measure under US GAAP and may not be comparable to similar financial measures disclosed by other issuers. Net debt, defined above, is a non-GAAP financial ratio, is used as a component of this non-GAAP financial ratio. See "Non-GAAP and Other Financial Measures" in this news release for information relating to this non-GAAP financial measure.

<sup>5</sup>Gran Tierra's first quarter-to-date 2023 total Company average production is for the period of January 1 - January 24, 2023.

**Corporate Presentation:**

Gran Tierra's Corporate Presentation has been updated and is available on the Company website at www.grantierra.com.

**Contact Information**

For investor and media inquiries please contact:

Gary Guidry, Chief Executive Officer

Ryan Ellson, Executive Vice President & Chief Financial Officer

Rodger Trimble, Vice President, Investor Relations

Tel: +1.403.265.3221

For more information on Gran Tierra please go to: www.grantierra.com.

**About Gran Tierra Energy Inc.**

Gran Tierra Energy Inc. together with its subsidiaries is an independent international energy company currently focused on oil and natural gas exploration and production in Colombia and Ecuador. The Company is currently developing its existing portfolio of assets in Colombia and Ecuador and will continue to pursue additional growth opportunities that would further strengthen the Company's portfolio. The Company's common stock trades on the NYSE American, the Toronto Stock Exchange and the London Stock Exchange under the ticker symbol GTE. Additional information concerning Gran Tierra is available at www.grantierra.com. Information on the Company's website (including the Corporate Presentation referenced above) does not constitute a part of this press release. Investor inquiries may be directed to info@grantierra.com or (403) 265-3221.

Gran Tierra's U.S. Securities and Exchange Commission ("SEC") filings are available on the SEC website at www.sec.gov. The Company's Canadian securities regulatory filings are available on SEDAR at www.sedar.com and UK regulatory filings are available on the National Storage Mechanism ("the NSM") website at https://data.fca.org.uk/#/nsm/nationalstoragemechanism. Gran Tierra's filings on the SEC, SEDAR and the NSM websites are not incorporated by reference into this press release.

**FORWARD LOOKING STATEMENTS ADVISORY**

This press release contains opinions, forecasts, projections, and other statements about future events or results that constitute forward-looking statements within the meaning of the United States Private Securities Litigation Reform Act of 1995, Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended, and financial outlook and forward looking information within the meaning of applicable Canadian securities laws (collectively, "forward-looking statements"), which can be identified by such terms as "expect," "plan," "forecast," "project," "objective," "will," "believe," "should," "could," "allow" and other terms that are forward-looking in nature. Such forward-looking statements include, but are not limited to, the Company's expectations regarding its capital program, and ability to fund the Company's exploration program over a period of time, 2022 and beyond outlook, the benefits of reduced capital spending and G&A expenses, well performance, production, the restart of production and workover activity, future development costs, infrastructure schedules, waterflood impacts and plans, growth of referenced reserves, forecast prices, five-year expected oil sales and cash flow and net revenue, estimated recovery factors, liquidity and access to capital, the Company's strategies and results thereof, the Company's operations including planned operations and developments, the impact of the COVID-19 pandemic and the Company's response thereto, disruptions to operations and the decline in industry conditions, and expectations regarding environmental commitments.

The forward-looking statements contained in this press release reflect several material factors and expectations and assumptions of Gran Tierra including, without limitation, that Gran Tierra will continue to conduct its operations in a manner consistent with its current expectations, the accuracy of testing and production results and seismic data, pricing and cost estimates (including with respect to commodity pricing and exchange rates), rig availability, the effects of drilling down-dip, the effects of waterflood and multi-stage fracture stimulation operations, the extent and effect of delivery disruptions, and the general continuance of current or, where applicable, assumed operational, regulatory and industry conditions including in areas of potential expansion, and the ability of Gran Tierra to execute its current business and operational plans in the manner currently planned. Gran Tierra believes the material factors, expectations and assumptions reflected in the forward-looking statements are reasonable at this time but no assurance can be given that these factors, expectations and assumptions will prove to be correct.

Among the important factors that could cause actual results to differ materially from those indicated by the forward-looking statements in this press release are: Gran Tierra's operations are located in South America and unexpected problems can arise due to guerilla activity, strikes, or local blockades or protests; technical difficulties and operational difficulties may arise which impact the production, transport or sale of our products; other disruptions to local operations; global health events (including the ongoing COVID-19 pandemic); global and regional changes in the demand, supply, prices, differentials or other market conditions affecting oil and gas, including inflation and changes resulting from a global health crisis, the Russian invasion of Ukraine, or from the imposition or lifting of crude oil production quotas or other actions that might be imposed by OPEC and other producing countries and the resulting company or third-party actions in response to such changes; changes in commodity prices, including volatility or a prolonged decline in these prices relative to historical or future expected levels; the risk that current global economic and credit conditions may impact oil prices and oil consumption more than Gran Tierra currently predicts, which could cause Gran Tierra to further modify its strategy and capital spending program; prices and markets for oil and natural gas are unpredictable and volatile; the effect of hedges, the accuracy of productive capacity of any particular field; geographic, political and weather conditions can impact the production, transport or sale of our products; the ability of Gran Tierra to execute its business plan and realize expected benefits from current initiatives; the risk that unexpected delays and difficulties in developing currently owned properties may occur; the ability to replace reserves and production and develop and manage reserves on an economically viable basis; the accuracy of testing and production results and seismic data, pricing and cost estimates (including with respect to commodity pricing and exchange rates); the risk profile of planned exploration activities; the effects of drilling down-dip; the effects of waterflood and multi-stage fracture stimulation operations; the extent and effect of delivery disruptions, equipment performance and costs; actions by third parties; the timely receipt of regulatory or other required approvals for our operating activities; the failure of exploratory drilling to result in commercial wells; unexpected delays due to the limited availability of drilling equipment and personnel; volatility or declines in the trading price of our common stock or bonds; the risk that Gran Tierra does not receive the anticipated benefits of government programs, including government tax refunds; Gran Tierra's ability to comply with financial covenants in its credit agreement and indentures and make borrowings under its credit agreement; and the risk factors detailed from time to time in Gran Tierra's periodic reports filed with the Securities and Exchange Commission, including, without limitation, under the caption "Risk Factors" in Gran Tierra's Annual Report on Form 10-K for the year ended December 31, 2021 and its other filings with the Securities and Exchange Commission. These filings are available on the Securities and Exchange Commission website at http://www.sec.gov and on SEDAR at www.sedar.com.

Statements relating to "reserves" are also deemed to be forward-looking statements, as they involve the implied assessment, based on certain estimates and assumptions, including that the reserves described can be profitably produced in the future.

Guidance is uncertain, particularly when given over extended periods of time, and results may be materially different. Although the current capital spending program and long term strategy of Gran Tierra is based upon the current expectations of the management of Gran Tierra, should any one of a number of issues arise, Gran Tierra may find it necessary to alter its business strategy and/or capital spending program and there can be no assurance as at the date of this press release as to how those funds may be reallocated or strategy changed and how that would impact Gran Tierra's results of operations and financing position. In particular, the unprecedented nature of the current pandemic and the resulting economic conditions may make it particularly difficult to identify risks or predict the degree to which identified risks will impact Gran Tierra's business and financial condition. All forward-looking statements are made as of the date of this press release and the fact that this press release remains available does not constitute a representation by Gran Tierra that Gran Tierra believes these forward-looking statements continue to be true as of any subsequent date. Actual results may vary materially from the expected results expressed in forward-looking statements. Gran Tierra disclaims any intention or obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise, except as expressly required by applicable securities laws. Gran Tierra's forward-looking statements are expressly qualified in their entirety by this cautionary statement.

The estimates of future net revenue, cash flow and interest and certain expenses may be considered to be future-oriented financial information or a financial outlook for the purposes of applicable Canadian securities laws. Financial outlook and future oriented financial information contained in this press release about prospective financial performance, financial position or cash flows are provided to give the reader a better understanding of the potential future performance of the Company in certain areas and are based on assumptions about future events, including economic conditions and proposed courses of action, based on management's assessment of the relevant information currently available, and to become available in the future. In particular, this press release contains projected operational and financial information for 2023 and for the next five years to allow readers to assess the Company's ability to fund its programs. These projections contain forward-looking statements and are based on a number of material assumptions and factors set out above. Actual results may differ significantly from the projections presented herein. The actual results of Gran Tierra's operations for any period could vary from the amounts set forth in these projections, and such variations may be material. See above for a discussion of the risks that could cause actual results to vary. The future-oriented financial information and financial outlooks contained in this press release have been approved by management as of the date of this press release. Readers are cautioned that any such financial outlook and future-oriented financial information contained herein should not be used for purposes other than those for which it is disclosed herein. The Company and its management believe that the prospective financial information has been prepared on a reasonable basis, reflecting management's best estimates and judgments, and represent, to the best of management's knowledge and opinion, the Company's expected course of action. However, because this information is highly subjective, it should not be relied on as necessarily indicative of future results.

**Non-GAAP Measures**

This press release includes non-GAAP measures which do not have a standardized meaning under GAAP. Investors are cautioned that these measures should not be construed as alternatives to net loss or other measures of financial performance as determined in accordance with GAAP. Gran Tierra's method of calculating these measures may differ from other companies and, accordingly, they may not be comparable to similar measures used by other companies.

Operating netback as presented is defined as oil sales less operating and transportation expenses. Management believes that operating netback is a useful supplemental measure for investors to analyze financial performance and provide an indication of the results generated by Gran Tierra's principal business activities prior to the consideration of other income and expenses. A reconciliation operating netback per boe to the most directly comparable measure calculated and presented in accordance with GAAP is as follows:

---

| | | |
|:---|:---|:---|
|  | **Three months ended December 31, 2022** | **Three months ended December 31, 2022** |
|  | **(Thousands of U.S Dollars)** | **($/bbl, per WI sales volumes)** |
| Oil sales | $162637 | $55.33 |
| Operating expenses | (46385) | (15.78) |
| Transportation expenses | (2433) | (0.83) |
| **Operating netback** | $**113819** | $**38.72** |

---

**Unaudited Financial Information**

Certain financial and operating results included in this press release, including debt, capital expenditures, and production information, are based on unaudited estimated results. These estimated results are subject to change upon completion of the Company's audited financial statements for the year ended December 31, 2022, and changes could be material. Gran Tierra anticipates filing its audited financial statements and related management's discussion and analysis for the year ended December 31, 2022 on or before February 21, 2023.

**DISCLOSURE OF OIL AND GAS INFORMATION**

Gran Tierra's Statement of Reserves Data and Other Oil and Gas Information on Form 51-101F1 dated effective as at December 31, 2022, which will include further disclosure of its oil and gas reserves and other oil and gas information in accordance with NI 51-101 forming the basis of this press release, will be available on SEDAR at www.sedar.com on or before February 21, 2023.

All reserves values, future net revenue and ancillary information contained in this press release as of December 31, 2022 are derived from a report with an effective date of December 31, 2022 prepared by McDaniel and calculated in compliance with NI 51-101 and COGEH.

Estimates of net present value and future net revenue contained herein do not necessarily represent fair market value. Estimates of reserves and future net revenue for individual properties may not reflect the same level of confidence as estimates of reserves and future net revenue for all properties, due to the effect of aggregation. There is no assurance that the forecast price and cost assumptions applied by McDaniel in evaluating Gran Tierra's reserves will be attained and variances could be material. All reserves assigned in the GTE McDaniel Reserves Report are located in Colombia and Ecuador and presented on a consolidated basis by foreign geographic area.

All evaluations of future net revenue contained in the GTE McDaniel Reserves Report are after the deduction of royalties, operating costs, development costs, production costs and abandonment and reclamation costs but before consideration of indirect costs such as administrative, overhead and other miscellaneous expenses. It should not be assumed that the estimates of future net revenues presented in this press release represent the fair market value of the reserves. There are numerous uncertainties inherent in estimating quantities of crude oil reserves and the future cash flows attributed to such reserves. The reserve and associated cash flow information set forth in the GTE McDaniel Reserves Report are estimates only.

References to a formation where evidence of hydrocarbons has been encountered is not necessarily an indicator that hydrocarbons will be recoverable in commercial quantities or in any estimated volume. Gran Tierra's reported production is a mix of light crude oil and medium and heavy crude oil for which there is no precise breakdown since the Company's oil sales volumes typically represent blends of more than one type of crude oil. Drilling locations disclosed herein are derived from the GTE McDaniel Reserves Report and account for drilling locations that have associated Undeveloped and Proved plus Probable Undeveloped reserves, as applicable. Well test results should be considered as preliminary and not necessarily indicative of long-term performance or of ultimate recovery. Well log interpretations indicating oil and gas accumulations are not necessarily indicative of future production or ultimate recovery. If it is indicated that a pressure transient analysis or well-test interpretation has not been carried out, any data disclosed in that respect should be considered preliminary until such analysis has been completed. References to thickness of "oil pay" or of a formation where evidence of hydrocarbons has been encountered is not necessarily an indicator that hydrocarbons will be recoverable in commercial quantities or in any estimated volume.

**Definitions**

Proved reserves are those reserves that can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated proved reserves.

Probable reserves are those additional reserves that are less certain to be recovered than proved reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the sum of the estimated proved plus probable reserves.

Possible reserves are those additional reserves that are less certain to be recovered than Probable reserves. There is a 10% probability that the quantities actually recovered will equal or exceed the sum of Proved plus Probable plus Possible reserves.

Proved developed producing reserves are those reserves that are expected to be recovered from completion intervals open at the time of the estimate. These reserves may be currently producing or, if shut-in, they must have previously been on production, and the date of resumption of production must be known with reasonable certainty.

Undeveloped reserves are those reserves expected to be recovered from known accumulations where a significant expenditure (e.g., when compared to the cost of drilling a well) is required to render them capable of production. They must fully meet the requirements of the reserves category (proved, probable, possible) to which they are assigned.

Certain terms used in this press release but not defined are defined in NI 51-101, CSA Staff Notice 51-324 – *Revised Glossary to NI 51-101, Standards of Disclosure for Oil and Gas Activities* ("**CSA Staff Notice 51-324**") and/or the COGEH and, unless the context otherwise requires, shall have the same meanings herein as in NI 51-101, CSA Staff Notice 51-324 and the COGEH, as the case may be.

**Oil and Gas Metrics**

This press release contains a number of oil and gas metrics, including NAV per share, F&D costs, F&D recycle ratio, operating netback, reserve life index, and reserves replacement, reserves per share and debt-adjusted production and reserves per share, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Company's performance; however, such measures are not reliable indicators of the future performance of the Company and future performance may not compare to the performance in previous periods.

&nbsp;&nbsp;&nbsp;&nbsp;• NAV
 per share is calculated as NPV10 (before or after tax, as applicable) of the applicable reserves
 category minus estimated debt, divided by the number of shares of Gran Tierra's common stock
 issued and outstanding. Management uses NAV per share as a measure of the relative change
 of Gran Tierra's net asset value over its outstanding common stock over a period of time.

&nbsp;&nbsp;&nbsp;&nbsp;• F&D
 costs are calculated as estimated exploration and development capital expenditures, excluding
 acquisitions and dispositions, divided by the applicable reserves additions both before and
 after changes in FDC costs. The calculation of F&D costs incorporates the change in FDC
 required to bring proved undeveloped and developed reserves into production. The aggregate
 of the exploration and development costs incurred in the financial year and the changes during
 that year in estimated FDC may not reflect the total F&D costs related to reserves additions
 for that year. Management uses F&D costs per boe as a measure of its ability to execute
 its capital program and of its asset quality.

&nbsp;&nbsp;&nbsp;&nbsp;• F&D
 recycle ratio is calculated as fourth quarter operating netback per WI sales volume divided
 by the appropriate F&D costs per boe. Management uses F&D recycle ratio as an indicator
 of profitability of its oil and gas activities.

&nbsp;&nbsp;&nbsp;&nbsp;• Operating
 netback is calculated as described in this press release. Management believes that operating
 netback is a useful supplemental measure for investors to analyze financial performance and
 provide an indication of the results generated by Gran Tierra's principal business activities
 prior to the consideration of other income and expenses.

&nbsp;&nbsp;&nbsp;&nbsp;• Reserve
 life index is calculated as reserves in the referenced category divided by the referenced
 estimated production. Management uses this measure to determine how long the booked reserves
 will last at current production rates if no further reserves were added.

&nbsp;&nbsp;&nbsp;&nbsp;• Reserves
 replacement is calculated as reserves in the referenced category divided by estimated referenced
 production. Management uses this measure to determine the relative change of its reserve
 base over a period of time.

&nbsp;&nbsp;&nbsp;&nbsp;• Reserves
 per share is calculated as reserves in the referenced category divided by the number of shares
 of Gran Tierra's common stock issued and outstanding. Management uses reserves per share
 as a measure of relative change of Gran Tierra's referenced reserves category over its outstanding
 common stock over a period of time.

&nbsp;&nbsp;&nbsp;&nbsp;• Net debt-adjusted production and
 reserves per share is calculated as described in this press release. Management believes
 that net debt-adjusted production per share is a useful supplemental measure for investors
 as it adjusts for the effects of changes in annual production in relation to the Company's
 capital structure. Management believes that net debt-adjusted reserves per share is a useful
 supplemental measures for investors as it adjusts for the effects of changes in reserves
 in relation to the Company's capital structure.

**Disclosure of Reserve Information and Cautionary Note to U.S. Investors**

Unless expressly stated otherwise, all estimates of proved, probable and possible reserves and related future net revenue disclosed in this press release have been prepared in accordance with NI 51-101. Estimates of reserves and future net revenue made in accordance with NI 51-101 will differ from corresponding estimates prepared in accordance with applicable U.S. Securities and Exchange Commission ("SEC") rules and disclosure requirements of the U.S. Financial Accounting Standards Board ("FASB"), and those differences may be material. NI 51-101, for example, requires disclosure of reserves and related future net revenue estimates based on forecast prices and costs, whereas SEC and FASB standards require that reserves and related future net revenue be estimated using average prices for the previous 12 months. In addition, NI 51-101 permits the presentation of reserves estimates on a "company gross" basis, representing Gran Tierra's working interest share before deduction of royalties, whereas SEC and FASB standards require the presentation of net reserve estimates after the deduction of royalties and similar payments. There are also differences in the technical reserves estimation standards applicable under NI 51-101 and, pursuant thereto, the COGEH, and those applicable under SEC and FASB requirements.

In addition to being a reporting issuer in certain Canadian jurisdictions, Gran Tierra is a registrant with the SEC and subject to domestic issuer reporting requirements under U.S. federal securities law, including with respect to the disclosure of reserves and other oil and gas information in accordance with U.S. federal securities law and applicable SEC rules and regulations (collectively, "SEC requirements"). Disclosure of such information in accordance with SEC requirements is included in the Company's Annual Report on Form 10-K and in other reports and materials filed with or furnished to the SEC and, as applicable, Canadian securities regulatory authorities. The SEC permits oil and gas companies that are subject to domestic issuer reporting requirements under U.S. federal securities law, in their filings with the SEC, to disclose only estimated proved, probable and possible reserves that meet the SEC's definitions of such terms. Gran Tierra has disclosed estimated proved, probable and possible reserves in its filings with the SEC. In addition, Gran Tierra prepares its financial statements in accordance with United States generally accepted accounting principles, which require that the notes to its annual financial statements include supplementary disclosure in respect of the Company's oil and gas activities, including estimates of its proved oil and gas reserves and a standardized measure of discounted future net cash flows relating to proved oil and gas reserve quantities. This supplementary financial statement disclosure is presented in accordance with FASB requirements, which align with corresponding SEC requirements concerning reserves estimation and reporting.

Proved reserves are reserves which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward from known reservoirs under existing economic conditions, operating methods, and government regulations prior to the time at which contracts providing the right to operate expires, unless evidence indicates that renewal is reasonably certain. Probable reserves are reserves that are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered. Estimates of probable reserves which may potentially be recoverable through additional drilling or recovery techniques are by nature more uncertain than estimates of proved reserves and accordingly are subject to substantially greater risk of not actually being realized by us. Possible reserves are reserves that are less certain to be recovered than probable reserves. Estimates of possible reserves are also inherently imprecise. Estimates of probable and possible reserves are also continually subject to revisions based on production history, results of additional exploration and development, price changes, and other factors.

The Company believes that the presentation of NPV10 is useful to investors because it presents (i) relative monetary significance of its oil and natural gas properties regardless of tax structure and (ii) relative size and value of its reserves to other companies. The Company also uses this measure when assessing the potential return on investment related to its oil and natural gas properties. NPV10 and the standardized measure of discounted future net cash flows do not purport to present the fair value of the Company's oil and gas reserves. The Company has not provided a reconciliation of NPV10 to the standardized measure of discounted future net cash flows because it is impracticable to do so.

Investors are urged to consider closely the disclosures and risk factors in the Company's Annual Report on Form 10-K, Quarterly Reports on Form 10-Q and in the other reports and filings with the SEC, available from the Company's offices or website. These reports can also be obtained from the SEC website at <u>www.sec.gov</u>.