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| Re:  | GeoGlobal Resources Inc.Reserve and Economic Evaluation – January 1, 2011 |
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|   | I, C. W. CHAPMAN, P. Eng., Professional Engineer of the City of Calgary, Alberta, Canada, officing at Suite 445, 708 – 11th Avenue S.W., hereby certify: |
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| 1. | THAT I am a registered Professional Engineer in the Province of Alberta and a member of the Australasian Institute of Mining and Metallurgy. |
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| 2. | THAT I graduated from the University of Alberta with a Bachelor of Science degree in Mechanical Engineering in 1971. |
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| 3. | THAT I have been employed in the petroleum industry since graduation by various companies and have been directly involved in reservoir engineering, petrophysics, operations, and evaluations during that time. |
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| 4. | THAT I have in excess of 25 years in the conduct of evaluation and engineering studies relating to oil & gas fields in Canada and around the world. |
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| 5. | THAT I participated directly in the evaluation of these assets and properties and preparation of this report for GeoGlobal Resources Inc., dated December 29, 2011 and the parameters and conditions employed in this evaluation were examined by me and adopted as representative and appropriate in establishing the value of these oil and gas properties according to the information available to date. |
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| 6. | THAT I have not, nor do I expect to receive, any direct or indirect interest in the properties or securities of GeoGlobal Resources Inc. its participants or any affiliate thereof. |
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| 7. | THAT I have not examined all of the documents pertaining to the ownership and agreements referred to in this report, or the chain of Title for the oil and gas properties discussed. |
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| 8. | A personal field examination of these properties was considered to be unnecessary because the data available from the Company's records and public sources was satisfactory for our purposes. |
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|   | I, ROY A. COLLVER, of the City of Calgary, Alberta, Canada, officing at Suite 445, 708 – 11th Avenue S.W., hereby certify: |
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| 1. | THAT I am a registered Engineer-In-Training in the Province of Alberta. |
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| 2. | THAT I graduated from Queen’s University in Kingston, Ontario with a Bachelor of Science degree in Engineering Physics in 2005. |
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| 3. | THAT I participated directly in the evaluation of these assets and properties and preparation of this report for GeoGlobal Resources Inc., dated December 29, 2011 and the parameters and conditions employed in this evaluation were examined by me and adopted as representative and appropriate in establishing the value of these oil and gas properties according to the information available to date. |
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| 4. | THAT I have not, nor do I expect to receive, any direct or indirect interest in the properties or securities of GeoGlobal Resources Inc., its participants or any affiliate thereof. |
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| 5. | THAT I have not examined all of the documents pertaining to the ownership and agreements referred to in this report, or the chain of Title for the oil and gas properties discussed. |
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| 6. | A personal field examination of these properties was considered to be unnecessary because the data available from the Company’s records and public sources was satisfactory for our purposes. |
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|   | Table 1:    | Summary of Company Reserves and Economics Before Tax |
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|   | Table 1T:  | Summary of Company Reserves and Economics After Tax |
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| (i)  | The area of the reservoir considered as proved includes: |
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|   | (A) | The area identified by drilling and limited by fluid contacts, if any, and |
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|   | (B) | Adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or gas on the basis of available geoscience and engineering data. |
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| (ii) | In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons (LKH) as seen in a well penetration unless geoscience, engineering, or performance data and reliable technology establishes a lower contact with reasonable certainty. |
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| (iii) | Where direct observation from well penetrations has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher contact with reasonable certainty. |
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| (iv) | Reserves which can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when: |
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|   | (A) | Successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based; and |
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|   | (B) | The project has been approved for development by all necessary parties and entities, including governmental entities. |
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| (v) | Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be the average price during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions. |
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| (i) | When deterministic methods are used, it is as likely as not that actual remaining quantities recovered will exceed the sum of estimated proved plus probable reserves. When probabilistic methods are used, there should be at least a 50% probability that the actual quantities recovered will equal or exceed the proved plus probable reserves estimates. |
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| (ii) | Probable reserves may be assigned to areas of a reservoir adjacent to proved reserves where data control or interpretations of available data are less certain, even if the interpreted reservoir continuity of structure or productivity does not meet the reasonable certainty criterion. Probable reserves may be assigned to areas that are structurally higher than the proved area if these areas are in communication with the proved reservoir. |
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| (iii) | Probable reserves estimates also include potential incremental quantities associated with a greater percentage recovery of the hydrocarbons in place than assumed for proved reserves. |
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| (i) | When deterministic methods are used, the total quantities ultimately recovered from a project have a low probability of exceeding proved plus probable plus possible reserves. When probabilistic methods are used, there should be at least a 10% probability that the total quantities ultimately recovered will equal or exceed the proved plus probable plus possible reserves estimates. |
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| (ii) | Possible reserves may be assigned to areas of a reservoir adjacent to probable reserves where data control and interpretations of available data are progressively less certain. Frequently, this will be in areas where geoscience and engineering data are unable to define clearly the area and vertical limits of commercial production from the reservoir by a defined project. |
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| (iii) | Possible reserves also include incremental quantities associated with a greater percentage recovery of the hydrocarbons in place than the recovery quantities assumed for probable reserves. |
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| (iv) | Possible reserves may be assigned where geoscience and engineering data identify directly adjacent portions of a reservoir within the same accumulation that may be separated from proved areas by faults with displacement less than formation thickness or other geological discontinuities and that have not been penetrated by a wellbore, and the registrant believes that such adjacent portions are in communication with the known (proved) reservoir. Possible reserves may be assigned to areas that are structurally higher or lower than the proved area if these areas are in communication with the proved reservoir. |
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| (v) | Pursuant to paragraph (a)(22)(iii) of this section, where direct observation has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves should be assigned in the structurally higher portions of the reservoir above the HKO only if the higher contact can be established with reasonable certainty through reliable technology. Portions of the reservoir that do not meet this reasonable certainty criterion may be assigned as probable and possible oil or gas based on reservoir fluid properties and pressure gradient interpretations. |
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|   | i)   | Ownership and Burdens have been derived from the Company's land records and other information from the Company as required for clarification;                                                                                                                                                     |
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|   | ii)  | Production data is acquired from public data sources, except for very recent data or certain wells which are provided directly by the Company;                                                                                                                                                    |
|   | iii) | Well data is accessed from the Company's well files and from public data sources;                                                                                                                                                                                                                 |
|   | iv)  | Operating Costs are based on actual revenue and expense statements provided by the Company for established properties or from discussions with the Company and our experience in the area for new or non-producing properties;                                                                    |
|   | v)   | Price differentials are derived from revenue statements, compared to actual posted prices for the appropriate benchmark price over a period of several months for established properties or from discussions with the Company and our experience in the area for new or non-producing properties; |
|   | vi)  | Timing of Development Plans and Capital estimates are normally determined by discussions with the Company together with our experience and judgment.                                                                                                                                              |

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|                                    |   | Net To Appraised Interest |   |
|-----------------------------------------|--------|---------------------------|--------|
|                                    |   | Reserves                  |   |   | Cumulative Cash Flow – M$ |   |
|                                    |   | Light and MediumOil MSTB  |   |   | Sales GasMMscf |   |   | NGLMbbls |   |   | Discounted at: |   |
|  Description                       |   | Gross                     |   |   | Net |   |   | Gross |   |   | Net |   |   | Gross |   |   | Net |   |   | Undisc. |   |   | 5%/year |   |   | 10%/year |   |   | 15%/year |   |   | 20%/year |   |
|  Proved Developed Producing        |   |                      |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |
|    Tarapur wells (Kalol) |   |                      | 55     |   |   |   | 55 |   |   |   | 155 |   |   |   | 155 |   |   |   | 0 |   |   |   | 0 |   |   |   | 3,611 |   |   |   | 3,185 |   |   |   | 2,856 |   |   |   | 2,596 |   |   |   | 2,386 |   |
| Total Proved Developed Producing        |   |                      | 55     |   |   |   | 55 |   |   |   | 155 |   |   |   | 155 |   |   |   | 0 |   |   |   | 0 |   |   |   | 3,611 |   |   |   | 3,185 |   |   |   | 2,856 |   |   |   | 2,596 |   |   |   | 2,386 |   |
|                                    |   |                      |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |
|  Probable                          |   |                      |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |
|    Tarapur wells (Kalol) |   |                      | 418    |   |   |   | 409 |   |   |   | 617 |   |   |   | 595 |   |   |   | 0 |   |   |   | 0 |   |   |   | 18,127 |   |   |   | 13,673 |   |   |   | 10,614 |   |   |   | 8,439 |   |   |   | 6,845 |   |
| Total Probable                          |   |                      | 418    |   |   |   | 409 |   |   |   | 617 |   |   |   | 595 |   |   |   | 0 |   |   |   | 0 |   |   |   | 18,127 |   |   |   | 13,673 |   |   |   | 10,614 |   |   |   | 8,439 |   |   |   | 6,845 |   |
| Total Proved Plus Probable              |   |                      | 473    |   |   |   | 464 |   |   |   | 772 |   |   |   | 750 |   |   |   | 0 |   |   |   | 0 |   |   |   | 21,738 |   |   |   | 16,858 |   |   |   | 13,470 |   |   |   | 11,035 |   |   |   | 9,231 |   |

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|                                   |   | Net To Appraised Interest |   |
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|                                   |   | Reserves                  |   |   | Cumulative Cash Flow – M$ |   |
|                                   |   | Light and MediumOil MSTB  |   |   | Sales GasMMscf |   |   | NGLMbbls |   |   | Discounted at: |   |
|  Description                      |   | Gross                     |   |   | Net |   |   | Gross |   |   | Net |   |   | Gross |   |   | Net |   |   | Undisc. |   |   | 5%/year |   |   | 10%/year |   |   | 15%/year |   |   | 20%/year |   |
|  Proved Developed Producing       |   |                      |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |
| Total Proved Developed Producing (BIT) |   |                      | 55     |   |   |   | 55 |   |   |   | 155 |   |   |   | 155 |   |   |   | 0 |   |   |   | 0 |   |   |   | 3,611 |   |   |   | 3,185 |   |   |   | 2,856 |   |   |   | 2,596 |   |   |   | 2,386 |   |
| Company Income Tax                     |   |                      | -      |   |   |   | - |   |   |   | - |   |   |   | - |   |   |   | - |   |   |   | - |   |   |   | - |   |   |   | - |   |   |   | - |   |   |   | - |   |   |   | - |   |
| Total Proved Developed Producing (AIT) |   |                      | 55     |   |   |   | 55 |   |   |   | 155 |   |   |   | 155 |   |   |   | 0 |   |   |   | 0 |   |   |   | 3,611 |   |   |   | 3,185 |   |   |   | 2,856 |   |   |   | 2,596 |   |   |   | 2,386 |   |
|                                   |   |                      |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |
|  Probable                         |   |                      |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |   |
|    Total Probable (BIT) |   |                      | 418    |   |   |   | 409 |   |   |   | 617 |   |   |   | 595 |   |   |   | 0 |   |   |   | 0 |   |   |   | 18,127 |   |   |   | 13,673 |   |   |   | 10,614 |   |   |   | 8,439 |   |   |   | 6,845 |   |
|    Company Income Tax   |   |                      | -      |   |   |   | - |   |   |   | - |   |   |   | - |   |   |   | - |   |   |   | - |   |   |   | (2,406 | ) |   |   | (1,475 | ) |   |   | (937 | ) |   |   | (613 | ) |   |   | (413 | ) |
| Total Probable (AIT)                   |   |                      | 418    |   |   |   | 409 |   |   |   | 617 |   |   |   | 595 |   |   |   | 0 |   |   |   | 0 |   |   |   | 15,721 |   |   |   | 12,198 |   |   |   | 9,677 |   |   |   | 7,826 |   |   |   | 6,432 |   |
| Total Proved Plus Probable (AIT)       |   |                      | 473    |   |   |   | 464 |   |   |   | 772 |   |   |   | 750 |   |   |   | 0 |   |   |   | 0 |   |   |   | 19,332 |   |   |   | 15,383 |   |   |   | 12,533 |   |   |   | 10,422 |   |   |   | 8,818 |   |

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