The Etom-1 well in the Lokichar Basin on Block 13T (Kenya) has reached a total depth of 6,561 feet (2,000 meters) and has discovered oil in the primary Auwerwer and Upper Lokhone target formations. The well encountered a range of between 16 and 65 feet (5 and 20 meters) of potential net pay sands based on wireline logging and drilling data. Oil has been recovered in MDT sample chambers which appears to be of similar quality to the oil found in the discoveries to the south. There is an additional 1,312 feet (400 meters) of porous sands in the Auwerwer and Lokhone Formations which also confirms the extension of thick reservoir sections into the northern portion of the basin. Oil and gas shows were noted throughout during drilling of the well confirming the extension of the petroleum system to the northern portion of the basin. Based on these positive drilling results, the partnership has agreed to extend the current 3D seismic survey over the northern portion of the basin where several additional large prospects have been identified by 2D seismic. The well has been suspended for potential future drill stem testing. Africa Oil holds a 50 percent working interest in this block, which is operated by Tullow Oil plc (Tullow) which holds the remaining 50 percent interest.
Drilling on the Ngamia-3 and Amosing 2/2A appraisal wells also in the Lokichar Basin on Block 10BB (Kenya) has also been completed. The results of these wells appear to confirm the thickness and lateral extent of the Auwerwer sands at both locations and also has extended the known oil column significantly downdip which will extend the proven field areas. The range of thickness of Auwerwer reservoir quality sands in all 6 penetrations of these 2 structures is between 479 and 721 feet (146 and 220 meters) and the sands appear consistent over the field areas. Net pay was encountered over multiple reservoir zones over a gross interval ranging from 1,640 to 4,921 feet (500 to 1500 meters). Pressure data seems to indicate that there could be pressure communication between many of these reservoirs. The upcoming extended well test programs on both of these fields will be designed to evaluate reservoir connectivity and help constrain estimates of flow rates and recovery factors for field development planning which are expected to commence early in 2015. Africa Oil holds a 50 percent working interest in this block, which is operated by Tullow which holds the remaining 50 percent interest.
Well testing has been completed on the previously announced Ewoi discovery on the eastern flank of the Lokichar Basin in Block 10BB (Kenya). The main zone of interest tested approximately 50 barrels of oil per day from the lower Lokhone sands which were relatively thin and of moderate reservoir quality. Data from the well may suggest that the wellbore may have been located in a downdip position and the Company is considering updip appraisal opportunities on this structure. The lightweight rig is currently testing the Twiga-2A appraisal well where two to three tests are planned.
The Company plans to move the 2 rigs that are completing drilling operations on the Etom and Amosing locations to the Kodos and Ekosowan locations and both are expected to spud in September. The Kodos well is the first well to be drilled in the highly prospective Central Kerio basin in Kenya Block 10BB and will target a 3 way dip closed feature against the main basin bounding fault similar to the Ngamia/Amosing/Twiga trend in the Lokichar Basin. The Ekosowan well is located on the western ‘string of pearl’ prospects in the Lokichar basin and is directly south of the Ngamia and Amosing fields which have demonstrated the thickest net pay and reservoir in the basin. Both wells are expected to be completed in the fourth quarter. Two additional new basin opening wells are planned to spud before the end of the year in the North Kerio Basin (Epir-1) and the North Turkana Basin in Block 10 BA (Engomo-1).
The Company has also spud an appraisal well on the previously announced Sala gas discovery in Block 9 onshore Kenya. The Sala-1 drilled a large 31 square mile (80 square kilometer) anticlinal feature along the northern basin bounding fault in the Cretaceous Anza graben and encountered several sandstone intervals which had oil and gas shows. An upper gas bearing interval tested dry gas at a maximum rate of 6 MMcf/d from an 82 foot (25 meter) net pay interval. The Sala-2 appraisal well is designed to test the updip extent of this main reservoir sand. A lower interval at Sala-1 also tested gas at low rates of dry gas from a 164 foot (50 meter) potential net pay interval and will also be accessed at this up-dip location. Africa Oil is the Operator of Block 9 with a 50 percent working interest. Marathon Oil Kenya Limited B.V. has the remaining 50 percent interest.
In Ethiopia, the Company continues to advance plans to commence a 2D seismic program in the Rift Basin Area Block which is expected to start later this year. The Company and its partners have also indicated their intent to enter the next exploration period in the South Omo block. Due to the extensive drilling and seismic program, no additional work commitments will be required during this period. The partnership plans to evaluate the four wells drilled to date to determine if additional drilling is warranted and, if so, which portion of the block is considered most prospective. The Company has informed the Ethiopian Government and its partners that it intends to withdraw from Blocks 7 and 8 in the Somali region. Although the El Kuran-3 well did demonstrate some oil and gas potential, the Company does not feel it is warranted to continue efforts at this time due to concerns over reservoir quality and commerciality.
Africa Oil CEO Keith Hill stated, “We are quite pleased with the Etom discovery which extends the proven petroleum system to the northern portion of the Lokichar basin and derisks several large prospects in that area. We are also encouraged that the Ngamia and Amosing appraisal wells have found thick reservoir and pay intervals that will give us further confidence that these two fields to anchor our development project and look forward to the results of the extended wells tests to confirm the reservoir performance. Our development activities are progressing in support of a Lokichar basin oil development project sanction at the end of 2015/early 2016. We have an exciting exploration portfolio in the new basin opening wells, of which we plan to drill 6 by the end of next year. We are confident that our early successes will be repeated in at least one additional new basin as we move forward to develop the large reserves we have discovered to date.”