Vetra: A Colombian story

Vetra Energia is a private Colombian based E&P with a sole focus on Colombia.

Its main asset is a 69.5% operated interest in the Sur Oriente block; Petroamerica is the partner on the block with 30.5% WI which it acquired through the merger with Suroco in 2014. Vetra Energia also has a 100% WI in the La Punta block and a 60% operated interest in VMM2 (40% Canacol) which contains the Mono Araña field.

In July 2013, Vetra Energia was acquired by a consortium led by ACON Investments and Capital International. The Vetra management team, along with private investors including oil & gas veteran Atul Gupta also participated in the acquisition. The Vetra management team and private investors participated through a vehicle called New VEG.

Vetra Holdings SARL was incorporated for the acquisition of Vetra Energia and is owned by the consortium members. Based on the company’s filings, the acquisition consideration is estimated to be c.USD440mm. This has largely been funded through pseudo-debt with USD265mm of Preferred Equity Certificates (“PECs”) issued to the consortium members and USD187mm of promissory notes issued to Vetra’s selling shareholders. The PECs carry no interest whereas the promissory notes carry a rate of 10% per annum.

In 2013, Vetra produced 5.6mmbbl or 15.4mbbl/d. However, latest filings with the ANH show that production had plummeted to 6mbbl/d in2014 suggesting that the consortium may have significantly overpaid for the acquisition. This view is supported by the valuation of the assets from public sources:

• Broker consensus read-through valuations of $92mm for Sur Oriente and <$1mm for the other assets
• Wood Mackenzie valuation of $63mm for Sur Oriente and <$1mm for the other assets
• Furthermore, Petroamerica recorded a write-down of $30.4mm on Sur Oriente in 2014

Sur Oriente is Vetra’s main asset and is located in the Putumayo Basin. It is owned through Consorcio Colombia Energy (“CCE”) in which Vetra holds a 69.5% interest and Petroamerica 30.5% interest. CCE holds a Crude Incremental Production Contract with Ecopetrol on Sur Oriente which entitles Ecopetrol a share of the block’s production which is determined by an R-factor. Petroamerica’s disclosure notes that Ecopetrol is entitled to 52% of production; the remaining 48% of production is shared between Vetra and Petroamerica per their interests in CCE. The block produces from three fields (Pinuna-Quillacinga, Cohembi and Quinde) and in 2014, gross production was c.14.3mbbl/d from six wells.

Production from Sur Oriente was historically trucked to the nearby Orito facilities and then exported via the Trans-Andean Pipeline (“OTA”) to the port of Tumaco on the Pacific coast where it is sold as the Colombian South Blend. In November 2014, a new export route was established for the Cohembi and Quinde fields with crude trucked to the Amazonas Station in Ecuador and transported through the Oleoducto de Crudos Pesados (“OCP”) pipeline which is expected to result in $8-10/bbl improvement in netbacks over time.

Pipeline export routes from Putumayo
Source: Petroamerica January 2015 corporate presentation

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Apache's Egyptian Jewel

Apache entered Egypt in 1994 and has since built up a dominant onshore position through a series of acquisitions and an aggressive exploration campaign. It is the largest acreage holder in the Western Desert and operates 24 licences. In 2010, Apache expanded its position through the acquisition of BP’s entire Western Desert portfolio as part of a wider transaction involving BP’s North American assets. In 2013, Apache divested 33.3% of its Egyptian portfolio to Sinopec for USD3.1bn in an effort to refocus on its North American business.

Apache’s Egyptian portfolio contains c.594mmboe of 2P reserves (Wood Mackenzie) as at the end of 2014 with about half of these reserves being gas. Gas production is an important part of Apache’s business, which is a material supplier of gas to the domestic market with a 12% market share (excluding Sinopec’s interest in the portfolio). All gas is sold to EGPC.

One of the biggest concerns for Egyptian operators over the past couple of years is the receivables balance due from the EGPC. To date, EGPC have not defaulted (to Apache or any other operator); in fact, EGPC have been aggressively paying down the balance since the beginning of 2015. To manage payment default risk, Apache has insurance with USD300mm of cover from the Overseas Private Investment Corporation  and this is in place until 2024.

Egypt has been one of Apache’s success stories, where production and cash flow have grown strongly with each USD1mm of investment generating USD2mm. This has be driven by strong and consistent exploration success – success rate has averaged above 80%. The company holds a large acreage position with 72% still undeveloped which will provide significant opportunities for the future.

Historical production

Cash flow growth

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Pricing Kenyan crude

The price a crude fetches is typically against a benchmark such as Brent, WTI or Urals and the underlying crude marketing agreement will detail the calculation of the premium or discount to such a benchmark as well as other adjustments. As Kenyan crude has never been marketed before, there is no established pricing for Lokichar crude – however, a hypothetical value can be calculated. One of the key determinants of crude pricing is crude quality with the heaviness (API gravity) and sourness (sulphur content) often being a point of focus.

The heaviness of a crude is measured in °API and is a measurement of how heavy or light a crude is compared to water. Crude with an above 10°API is lighter than and will therefore float on water (i.e. is less dense). Heavier crude oils have longer hydrocarbon chain lengths and are generally less desirable as it is more difficult to convert them into more useful petroleum products. Light crude oil is defined as having an API gravity of greater than 31.1° API and a heavy crude oil has an API gravity of below 22.3° API.

The sourness of a crude is a measure of the level of sulphur by weight. Crude with less than 0.5% sulphur is considered sweet and above this level is sour. Sour crude is less desirable as the sulphur is a corrosive material and requires more processing; there are also increasingly strict limits on the sulphur content of gasoline and other petroleum products.

Amosing well testshave flowed oil between 31° to 38° API and is therefore considered a light oil; sulphur content is generally less than 0.1%. Based on test results to date, Lokichar crude is relatively high quality and should fetch pricing broadly in line with Brent (see bubble chart).

Other determinants of crude oil pricing are:

• Location - the total cost to a buyer is the wellhead price plus the cost of transportation and freight which will be benchmarked against other sources of supply
• Logistics – for long haul crudes, larger parcels tend to command a premium as per unit freight costs are lower; this also requires the loading and destination ports to be able handle larger vessels as well as having sufficient storage facilities
• Destination – refineries have different configurations in that they are setup to process different kinds of crudes. Not all refineries require light, sweet crudes and some are built to handle heavier crudes and will desire certain crude blends over others 

Refiners pay particular attention to the crude assay, or the chemical composition of the crude – this goes beyond looking at the API gravity and sulphur content mentioned above. For example, the pour point, wax content, level of other impurities are important considerations and depending on the refinery product slate, the refinery yields are also key (this refers to the relative proportion of the different hydrocarbon chain lengths in the oil). BP’s assay for Brent is shown below.

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