Genel grows in Kurdistan

Genel is acquiring interests in the Chevron operated Sarta and Qara Dagh blocks.

Genel will acquire a 30% interest in Sarta and will pay 50% of the field development costs until a specific production target is reached; there will also be a production milestone contingent payment – total spend by Genel is estimated at USD60 million. Chevron will retain a 50% interest and the KRG holds the remaining 2% interest which is carried by the oil companies. Sarta currently has three wells with both Sarta-2 and Sarta-3 having flow tested at c.7,500bopd. The first phase of development will produce from these wells with initial export via trucking.

Qara Dagh is an appraisal licence and Genel will acquire a 40% operated interest through a carry. Chevron will retain 40% interest and the KRG holds the remaining 20% interest. The last well (Qara Dagh-1) was drilled in 2011 which showed complex geology. Genel plans to drill Qara Dagh-2 in 2020.

Genel is slowly rebuilding its profile following a series of disastrous downgrades in Kurdistan – this is now behind the company and it is receiving good cash flow from the Tawke production which it can now reinvest in Kurdistan.

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Saudi Arabia announces upgrade to oil and gas reserve base

The Ministry of Energy, Industry and Mineral Resources of Saudi Arabia has announced an upward revision to the Kingdom's proven oil and gas reserves, following an independent certification of oil and gas reserves in Saudi Aramco's concession area conducted by leading consultants DeGolyer and MacNaughton (D&M).

The Kingdom previously announced that oil and gas reserves as of 31 December 2017 were 266.3 billion barrels of oil and 307.9 trillion standard cubic feet of gas respectively. Of these, the estimated proven oil and gas reserves in Saudi Aramco's concession area were 260.9 billion barrels of oil and 302.3 trillion standard cubic feet of gas. Following the certification, Saudi Aramco's concession area oil reserves at year-end 2017 would have been 2.2 billion barrels higher or 263.1 billion barrels of oil and 319.5 trillion standard cubic feet of gas.

In addition to Saudi Aramco concession area reserves, the Kingdom also owns half of the oil reserves in the Partitioned Zone jointly owned by Saudi Arabia and the State of Kuwait. The Kingdom's share of the Partitioned Zone oil reserves (onshore and offshore combined) is 5.4 billion barrels and the corresponding gas reserves is 5.6 TCF.

So, including the D&M revision of oil reserves in the Saudi Aramco's concession area, the Kingdom's total proven oil and gas reserves as of year-end 2017 would have been about 268.5 billion barrels of oil and 325.1 trillion standard cubic feet of gas, respectively.

The Minister of Energy, Industry, and Mineral Resources, His Excellency Khalid Al-Falih, noted that this also highlighted three other important realities:

• That these vast reserves are also among the lowest cost in the world, backed by world-leading economies of scale.
• That the carbon intensity of Saudi Arabia’s oil and corresponding gas flaring are among the very lowest in the world, and he called on the industry to use this metric alongside profitability.
• And that it was a tribute to the importance the Kingdom places on integrity, the discipline and world-leading excellence of Saudi Aramco's operations and employees.

'This certification underscores why every barrel we produce is the most profitable in the world, and why we believe Saudi Aramco is the world’s most valuable company and indeed the world's most important,' His Excellency said.

Background:

The results of the D&M's evaluation have conclusively proved the integrity, robustness, and accuracy of the Kingdom's – and in particular Saudi Aramco's - internally-conducted estimates of its hydrocarbon reserves.

The Kingdom's previous evaluations of its hydrocarbon reserves as of the end of 2017, including Saudi Arabia's share of the Partitioned Zone (PZ), were around 266.3 billion barrels of oil (Saudi Aramco 260.9 billion barrels and 5.4 billion barrels in the PZ), and around 307.9 trillion standard cubic feet of natural gas.

It is common industry practice to focus the reserves audit on the major reservoirs in a company's portfolio. Accordingly, D&M evaluated 54 major oil reservoirs operated by Saudi Aramco, out of 368 in Saudi Aramco’s portfolio. These 54 reservoirs alone make up approx. 80% of the Saudi Aramco's reserves in the concession area 260.9 billion barrels oil reserves estimate. D&M's certification confirms that, as of December 31, 2017, these 54 reservoirs contained 213.1 billion barrels of proved oil reserves – conventionally known as '1P' – assessed on a full reserve life basis. This compares to a figure of 210.9 billion barrels of oil for the same reservoirs as estimated internally by Saudi Aramco. D&M's oil reserves certification being 1.0% higher (+2.2 billion barrels) than Saudi Aramco's.

In terms of gas certification, the Ministry noted that D&M evaluated gas reserves in 77 major reservoirs operated by Saudi Aramco, that alone make up approximately 60% of the Kingdom's 302.3 trillion standard cubic feet (tscf) gas reserves estimate. D&M's certification confirms that, as of December 31, 2017, these 77 reservoirs contained 204.9 tscf of proven gas. This certification is 9.2% higher (+ 17.2 tscf) than Saudi Aramco's internal estimate for the same reservoirs, which proves that the Kingdom adopts highly cautious methods in evaluating its oil and gas reserves.

As indicated above, D&M’s evaluation was limited to 'booked' oil and gas resources in the Saudi Aramco's concession area and does not cover other available hydrocarbon resources in the Kingdom, such as the significant unconventional gas reserves recently discovered but not yet 'booked' by Saudi Aramco or the Kingdom. Nor did the D&M cover the Kingdom's share of the reserves in the Saudi–Kuwaiti Partitioned Zone, which has both an onshore and offshore component. The onshore part is estimated by Saudi Arabian Chevron at 2,923 million barrels, while its share of gas reserves in that area is estimated at 877 billion standard cubic feet. In addition, the Kingdom’s share of oil reserves in the Offshore Partitioned Zone is estimated by Aramco Gulf Operations Company at 2,476 million barrels, while its share of gas reserves in the same area is estimated at 4,749 billion standard cubic feet. So, the Kingdom’s share of the total oil and gas reserves in the Partitioned Zone, onshore and offshore combined, is roughly 5.4 billion barrels and 5.6 trillion cubic feet of gas.

This independent evaluation further underscores the Kingdom's strong position and reputation for reliable oil production and supply. It also represents a strong validation of both the robustness and accuracy of Saudi Aramco's internal estimation techniques and processes, and provides in-depth insight into the unique size of the oil and gas reserves in Saudi Arabia.

'This independent third-party certification is in line with the Kingdom's Vision 2030, which promotes transparency, accuracy, and quality of all kinds of critical data. This reflects the continued direction and support provided to the Saudi petroleum industry by the Custodian of the Two Holy Mosques, King Salman bin Abdulaziz Al Saud; and HRH Crown Prince Mohammad bin Salman bin Abdulaziz,' His Excellency said.

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Valeura: Turkey's new gas supplier

Valeura continues to make good progress in Turkey where the company announced a technical success at the Inanli-1 well in November. The well continues to be tested into 2019.

Turkey is structurally short gas, importing gas by pipeline and LNG - LNG regasification capacity is 12bcm/year with cargoes from Algeria, Nigeria and the Middle East. Domestic gas production is therefore long awaited and with Valeura owning the local pipeline network around its licence areas, it is in a good position to start supplying the grid once it is in a position to proceed to development.

The recent gas price hike by BOTAS is useful as well - not only does it protect the gas price in USD terms, but the price increase for local buyers has incentivised such buyers to turn to Valeura gas which has the freedom to sell directly to end users.

The domestic gas prices for power producers are: USD9/mmbtu for power producers, USD6.8/mmbtu for industrial customers and USD5/mmbtu for domestic users. Valeura can make inroads with buyers who currently take gas at the higher end of the pricing range from BOTAS.

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US resource play map

Reference map of major US L48 resource plays

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Sponsor completion guarantees in LNG construction financing: Part II

As the world of North American LNG financings continue to evolve, OGInsights explores the use of completion guarantees in construction financings.

In Part II of this two part series, we look at the conditions precedent to project completion which typically need to be satisfied for release of the completion guarantee by lenders.

Construction criteria requires "substantial completion" under the EPC Contract. In addition, operational tests must be satisfactory and includes production of on-specification LNG for a continuous 90-day period.

At completion, maximum stated debt to equity ratio is not to be exceeded - should the ratio be too high, project sponsors are required inject capital to bring the ratio within covenanted levels. Operating account and Debt Service Reserve Accounts are also to be funded to required levels.

From a legal perspective, project agreements and finance documents must be in full force and all governmental authorisations need to be in place, together with certification of environmental and social compliance in line with covenant requirements.

Financing structures continue to evolve to support LNG projects with lenders and sponsors driving the innovation to (i) enable projects and (ii) improve project economics whilst managing the risk that lenders are exposed to.

In Part I, OGInsights covered the use of and reasons for project completion guarantees from a sponsor perspective.

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Sponsor completion guarantees in LNG construction financing: Part I

As the world of North American LNG financings continue to evolve, OGInsights explores the use of completion guarantees in construction financings.

At a high level, the project sponsor guarantees debt service under a guarantee until the construction is complete. To the extent that a project does not reach completion (normally by a certain long-stop date), then the sponsor will be obliged to repay all of the debt under the guarantee.

The provision of a guarantee comes with a number of benefits:

1. Lenders are more likely to agree to the equity funding of a project to be back-ended (i.e. construction costs are first funded by debt before equity rather than pro rata). This improves project economics (NPV and IRR).
2. Lenders will allow use of pre-project completion cash flows as a source of “equity” funding towards the project, thus replacing “hard” equity contributions. In the absence of a guarantee, lenders typically do not give credit to such uncontracted cash flow and such cash generated is trapped until project completion is achieved (as normally insisted upon by lenders). When a guarantee is in place, lenders are more or less agnostic to whether pre-completion LNG sales are contracted or spot sales and can give credit to such cash flows.
3. Lower pre-completion debt costs – reduced commitment fees and margins, reflecting that of the sponsor corporate credit strength (with normal adjustments for pricing and tenor). Pricing could be c.15-30bps cheaper under a construction guarantee structure fr example

One possible downside is that higher amounts of debt are drawn in the early years of construction (vs. when no guarantee is in place) if equity funding is back-ended, and hence interest costs could be higher, although this is partly offset by the lower debt pricing mentioned above.

Note that in a financing without a completion guarantee, lenders require hedging at financial close of the facility with a substantial amount (typically >60%) under either fixed interest rate or hedged throughout the construction and operations period. A construction guarantee provides more flexibility with regard to hedging during the pre-completion/construction period as the interest rate risk is borne by the sponsor; at project completion, lenders will require fixed rate/hedging in place concurrent with the release of the guarantee.

Financing structures continue to evolve to support LNG projects with lenders and sponsors driving the innovation to (i) enable projects and (ii) improve project economics whilst managing the risk that lenders are exposed to.

In Part II, OGInsights explores the conditions that constitute project completion.

#US #LNG #financing

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Valuera nears TDs at Inanli-1

Valeura has reached 4,145m on the Inanli-1 well (TD 5,000m, c.800m deeper than Yamalik-1).

It has encountered over-pressured gas with a c.40% net-to-gross, similar to that of Yamalik-1, with gas flows - all pointing to promising results. In addition, the well has encountered more naturally fractured rock than encountered in Yamalik-1 with increased gas levels recorded at the fractured intervals.

Drilling is continuing to 5,000m with an extensive set of logging and well tests planned. Operations are expected to be completed in January with fracking and flow testing expected to commence around the end of Q1/19. Inanli-1 is the final well to be funded by Equinor.

Devepinar-1 appraisal well is the next scheduled to be drilled following completion of Inanli-1.

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