Second DST Test Successfully Completes Lengo Appraisal

AWE Limited reported that a second successful drill stem test was conducted at the Lengo-2 appraisal well that is situated in the Bulu Production Sharing Contract offshore East Java, Indonesia. The test achieved a maximum gas flow rate of 21.2 million standard cubic feet per day (MMcf/d).

AWE, a partner on the field, reported that two further cores were cut in the Kujung I reservoir from 2,485 to 2,571 feet, recovering an estimated 79 feet of carbonate Kujung I reservoir formation. Gas samples were collected and a final result of the compositional analysis from both DST tests is expected in coming weeks.

"The results from the two DSTs at Lengo-2, combined with the data we have previously acquired from the Lengo-1 well, will be used by the Joint Venture as the basis for evaluating the future commercial development potential of the Lengo field," said Bruce Clement, AWE's managing director in a statement. "The growing domestic energy market in East Java is an attractive destination for this gas resource, should it prove commercial."

The Randolph Yost (300' ILC) jackup is drilling the appraisal well to a total depth of about 2,717 feet. Upon completion of the logging program, the well will be plugged and abandoned as planned.

KrisEnergy Satria Limited operates the license with a 42.5 percent stake. Partners include AWE Limited (42.5%), PT Satria Energindo (10%) and PT. Satria Wijaya Kusuma (5%).

With more than 10 years of journalism experience, Robin Dupre specializes in the offshore sector of the oil and gas industry. Email Robin at rdupre@rigzone.com.

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Ruspetro Reports Progress with Appraisal Drilling

West Siberia-focused Ruspetro reported Wednesday that it has made progress with appraisal drilling at its field in the Khanty-Mansiysk region.

Ruspetro said that preparations – including pipelines, power, road and bridge access – had been completed at the Pad 4 area in the gas/condensate part of the field and that drilling had commenced. The company will use drilling here to continue its appraisal and characterization of the gas/condensate formations.

Meanwhile, rig build-up preparations are ongoing at the Pad 23 area, which is located in the crude oil-producing western part of the field, and two further wells are to be converted into water injectors in the Pad 21 area during the third quarter of 2013.

Ruspetro said that its average production rate for the first quarter of the year was 5,986 barrels of oil per day. During April, this production rate fell to 5,452 bopd.

Ruspetro Chief Executive Don Wolcott commented in a statement:

"In line with the plan laid out at our Strategic Review Presentation of 12 April, we are pleased with the progress made in our appraisal drilling program. Pad 4 has now been completed, with infrastructure in place and drilling commenced. Appraisal drilling from Pad 4 will enable us to further delineate the gas and condensate reservoir in the North.

"Drilling from Pad 23 will delineate the productive sands going west from the prolific crude oil producing Pad 21 area. Our discussions with Sberbank are progressing and we are confident that they will be completed in the first half of 2013."

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Second DST Test Successfully Completes Lengo Appraisal

AWE Limited reported that a second successful drill stem test was conducted at the Lengo-2 appraisal well that is situated in the Bulu Production Sharing Contract offshore East Java, Indonesia. The test achieved a maximum gas flow rate of 21.2 million standard cubic feet per day (MMcf/d).

AWE, a partner on the field, reported that two further cores were cut in the Kujung I reservoir from 2,485 to 2,571 feet, recovering an estimated 79 feet of carbonate Kujung I reservoir formation. Gas samples were collected and a final result of the compositional analysis from both DST tests is expected in coming weeks.

"The results from the two DSTs at Lengo-2, combined with the data we have previously acquired from the Lengo-1 well, will be used by the Joint Venture as the basis for evaluating the future commercial development potential of the Lengo field," said Bruce Clement, AWE's managing director in a statement. "The growing domestic energy market in East Java is an attractive destination for this gas resource, should it prove commercial."

The Randolph Yost (300' ILC) jackup is drilling the appraisal well to a total depth of about 2,717 feet. Upon completion of the logging program, the well will be plugged and abandoned as planned.

KrisEnergy Satria Limited operates the license with a 42.5 percent stake. Partners include AWE Limited (42.5%), PT Satria Energindo (10%) and PT. Satria Wijaya Kusuma (5%).

With more than 10 years of journalism experience, Robin Dupre specializes in the offshore sector of the oil and gas industry. Email Robin at rdupre@rigzone.com.

Generated by readers, the comments included herein do not reflect the views and opinions of Rigzone. All comments are subject to editorial review. Off-topic, inappropriate or insulting comments will be removed.
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Total Gets NPD Nod for North Sea Appraisal

The Norwegian Petroleum Directorate has granted Total E&P Norge AS a drilling permit for well 7225/3-2, cf. Section 8 of the Resource Management Regulations.

Wellbore 7225/3-2 will be drilled from the drilling facility Leiv Eiriksson (UDW semisub) at position 72 57' 05.17" north and 25 58' 23.34" east.

The drilling program for well 7225/3-2 relates to drilling of an appraisal well in production license 535. Total E&P Norge AS is the operator with an ownership interest of 40 percent. The other licensees are North Energy ASA with 20 percent, Det norske oljeselskap ASA with 20 percent, Valiant Petroleum Norge AS with 13 percent and Rocksource Exploration Norway AS with 7 percent.

The production license consists of blocks 7225/3 and 7226/1, and was awarded in the 20th licensing round in 2009.

Wildcat well 7225/3-2 is the second exploration well in production license 535.

The permit is contingent upon the operator securing all other permits and consents required by other authorities prior to starting drilling activities.

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BP to Proceed with Clair Phase 3 Appraisal

BP announced Thursday that it and its partners have decided to proceed with a two-year appraisal program that will look at developing a third phase of the giant Clair field in the North Sea, west of Shetlands.

The initial commitment involves a two-year program to drill five appraisal wells. This could increase to between eight and 12 wells, depending on results from these first wells. Drilling of the first well commenced recently.

The objectives of the program are to provide greater certainty on overall reservoir volumes, including their distribution and fluid characteristics; to evaluate technologies to improve recovery from Greater Clair; and to test the possibility of new standalone developments and linkages to Clair Ridge.

BP Regional President for the North Sea Trevor Garlick commented in a company statement:

"This is a major milestone and a further big commitment to the west of Shetland by BP and its co-venturers. If successful, the appraisal programme could pave the way for a third phase of development at Clair – this is now a real possibility."

UK Energy Secretary Ed Davey added:

"This announcement by BP of a two year appraisal programme for the Greater Clair area West of Shetland is excellent news. It shows the industry's commitment to maximise the potential in this area, which could hold up to 17 percent of our oil and gas reserves."

"Greater Clair proves there is still a long future for oil and gas production in the North Sea and will give confidence to new recruits that the industry offers a career for life."

Discovered in 1997, the Clair field is located almost 50 miles west of Shetland and extends over an area of 85 square miles. Hydrocarbons initially in place have been estimated at around eight billion barrels of oil equivalent.

So far, the first development phase at Clair have seen BP and its partners process around 90 million barrels. Phase 2, in which production is expected to commence in 2016, is expected to lead to an estimated 640 million barrels of oil produced over 40 years, and will also provide a hub for future expansion.

BP is the operator of Clair, with a 27.62-percent interest. Partners in the field include: Britoil (0.98%), ConocoPhillips UK Sigma (24%), Chevron North Sea (19.42%), Enterprise Oil Limited (18.68%) and Shell Clair UK (9.3%).

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BP to Proceed with Clair Phase 3 Appraisal

BP announced Thursday that it and its partners have decided to proceed with a two-year appraisal program that will look at developing a third phase of the giant Clair field in the North Sea, west of Shetlands.

The initial commitment involves a two-year program to drill five appraisal wells. This could increase to between eight and 12 wells, depending on results from these first wells. Drilling of the first well commenced recently.

The objectives of the program are to provide greater certainty on overall reservoir volumes, including their distribution and fluid characteristics; to evaluate technologies to improve recovery from Greater Clair; and to test the possibility of new standalone developments and linkages to Clair Ridge.

BP Regional President for the North Sea Trevor Garlick commented in a company statement:

"This is a major milestone and a further big commitment to the west of Shetland by BP and its co-venturers. If successful, the appraisal programme could pave the way for a third phase of development at Clair – this is now a real possibility."

UK Energy Secretary Ed Davey added:

"This announcement by BP of a two year appraisal programme for the Greater Clair area West of Shetland is excellent news. It shows the industry's commitment to maximise the potential in this area, which could hold up to 17 percent of our oil and gas reserves."

"Greater Clair proves there is still a long future for oil and gas production in the North Sea and will give confidence to new recruits that the industry offers a career for life."

Discovered in 1997, the Clair field is located almost 50 miles west of Shetland and extends over an area of 85 square miles. Hydrocarbons initially in place have been estimated at around eight billion barrels of oil equivalent.

So far, the first development phase at Clair have seen BP and its partners process around 90 million barrels. Phase 2, in which production is expected to commence in 2016, is expected to lead to an estimated 640 million barrels of oil produced over 40 years, and will also provide a hub for future expansion.

BP is the operator of Clair, with a 27.62-percent interest. Partners in the field include: Britoil (0.98%), ConocoPhillips UK Sigma (24%), Chevron North Sea (19.42%), Enterprise Oil Limited (18.68%) and Shell Clair UK (9.3%).

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Statoil Spuds New Johan Sverdrup Appraisal Well

Sweden's Lundin Petroleum reported Tuesday the spud of appraisal well 16/2-17S on the Statoil-operated production license 265 on the Johan Sverdrup discovery in the Norwegian North Sea.

The well is located close to the western-bounding fault of the Johan Sverdrup discovery and its main objective is to investigate the Jurassic reservoir thickness, quality and distribution close to the fault – approximately a mile southwest of appraisal well 16/2-8 and 1.5 miles west of appraisal well 16/2-11.

The planned total depth is approximately 6,750 feet below mean sea level. The well will be drilled by the Ocean Vanguard (DW semisub) rig in an operation expected to take around 55 days.

Statoil's partners in the well include Petoro, with a 30-percent stake, Det norske oljeselskap, with 20 percent, and Lundin Norway, which has a 10-percent interest.

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OMV to Boost Exploration, Appraisal Spend in 2013

Austria's OMV said Thursday that it will see a significant increase in its exploration and appraisal expenditure during 2013 compared to 2012.

Reporting its fourth quarter results for 2012, the firm said its plans include high-impact wells this year at Bonna, Wisting and Apollo in the Barents Sea, as well as at Matuku, offshore New Zealand.

OMV said it was expecting a final investment decision in 2013 for the North Sea's Rosebank project, offshore the Shetland Islands, in which it has a 20-percent stake. Meanwhile, in Romania it expects further exploration to take place on the Neptun block after an ongoing 3D seismic survey there is completed.

In Libya, the firm expects production to remain at current levels after volumes recovered in 2012. Production in Libya was badly disrupted in 2011 by the revolution in the country.

OMV warned that the security situation remains volatile in Yemen, where it has recovered production following the repair of an export pipeline.

In the Kurdistan region of Iraq, OMV said that extended well test facilities for its Bina Bawi development are under construction and production testing for sale into the local market is expected to start during the first half of this year.

For 2013 OMV expects production will be broadly similar to that achieved in 2012. Total hydrocarbon production for the fourth quarter of 2012 came in at 301,000 barrels of oil equivalent per day (4Q 2011: 289,000 boepd).

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Bowleven Strikes Oil at Appraisal Offshore Cameroon

Bowleven announced that the IM-5 well drilling offshore Cameroon has now reached the Middle Isongo primary objective of the well and has encountered liquids-rich hydrocarbon-bearing pay in both this and the Intra Isongo reservoir objectives based on the results of drilling, core analysis, wireline logs, fluid samples and pressure data.

The well, which was designed to appraise the reservoir and fluid properties of the Middle Isongo and to explore the additional potential of the Intra Isongo, has reached TD of 3,430 meters MD. The forward program is to set liner and conduct testing operations.

Validation of sufficient gas volumes to meet fertilizer plant requirements.Samples obtained during logging confirm the presence of liquids-rich hydrocarbons in the Intra and Middle Isongo intervals.Approximately 82 feet (25 meters) of log evaluated net hydrocarbon-bearing pay over a gross interval of approximately 108 feet (33 meters) encountered in the Middle Isongo primary objective.Log evaluation indicates hydrocarbon water contact (HWC) at approximately 11,024 feet (3,360 meters) MD, extending and deepening the hydrocarbon column intersected at IM-3 by 305 feet (93 meters), with total column height intersected by the two wells of 476 feet (145 meters).A further 66 feet (20 meters) of high quality sands were encountered directly beneath the HWC.Approximately 230 feet (70 meters) of net hydrocarbon-bearing pay over a gross interval of approximately 262 feet (80 meters) now confirmed in the Intra Isongo following log evaluation, with hydrocarbon down to the base of the reservoir.Preparing for testing operations.

The primary objective of the IM-5 appraisal/development well was to appraise the reservoir and fluid properties of the Middle Isongo sands. The secondary objective of the well was to investigate the additional potential of the Intra Isongo exploration prospect, a potentially extensive amplitude supported channel system potentially comprising both structural and stratigraphic trapping elements. The well was also designed to intersect the Upper Isongo sands and confirm that these were present at this location and water-bearing as prognosed.

Since Bowleven's previous IM-5 drilling update announcement on 30 January 2013, the well, which is drilling in shallow water depths of around 184 feet (56 meters), has been drilled to a depth of 11,253 feet (3,430 meters) MD. Logging activities have been performed and core was acquired as planned in the Middle Isongo reservoir interval.

Bowleven, as operator, provides the following updates on the reservoir sections intersected:

The well has intersected a log evaluated gross hydrocarbon interval of approximately 108 feet (33 meters). The net pay is estimated to be approximately 82 feet (25 meters). Log evaluation indicates that a HWC has been encountered at approximately 11,024 feet (3,360 meters) MD, extending and deepening the hydrocarbon column encountered at the IM-3 well by 305 feet (93 meters). A further 66 feet (20 meters) of reservoir quality sands were encountered beneath the HWC and the well was still in sand at TD.

Core analysis and fluid samples acquired during operations confirm the presence of liquids-rich hydrocarbons. Initial sample analysis suggests a liquids to gas ratio in the region of 150 bbls/mmscf.

The well has intersected a log evaluated gross hydrocarbon interval of approximately 262 feet (80 meters) in reservoir sands which correspond to the seismic event identified pre-drill. The net pay is estimated to be approximately 230 feet (70 meters). No HWC was encountered.

Fluid samples acquired during logging activities confirm the presence of liquids rich hydrocarbons. Initial sample analysis suggests a liquids to gas ratio in the region of 200 bbls/mmscf.

The well has intersected approximately 105 feet (32 meters) of high quality reservoir sands in the Upper Isongo. As predicted, log evaluation indicates these sands are water-bearing at this location. Sand thickness and quality were consistent with pre-drill expectations.

The plan is to set liner prior to testing. The testing program is currently being finalized.

Updated volumetrics for the Middle and Intra Isongo will be generated following completion of the well (including testing) and the integration and evaluation of well and seismic data. Based on preliminary analysis an increase in both the P90 and P50 volumes is anticipated.

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Johan Sverdrup Appraisal Well Successful

Sweden's Lundin Petroleum and the Norwegian Petroleum Directorate (NPD) announced Friday that the 16/2-16AT2 appraisal well on the Johan Sverdrup discovery on production license 501 has been successfully completed.

The well was drilled as a side track to well 16/2-16 on the northeastern flank of the Johan Sverdrup field – approximately 0.6 miles to the west of the main bore hole. The objective of the side track was to improve the understanding of the lateral variations in reservoir qualities and relations to oil-water contacts in the neighboring wells.

Lundin (the operator, with a 40-percent interest) reported that the well encountered a gross oil column of approximately 98 feet with "largely excellent" reservoir quality within the Jurassic reservoir sequence. The acquired data also confirms an oil-water contact at approximately the same level as in well 16/2-10, which is the deepest observed at Johan Sverdrup.

"We are very pleased with the results of the latest appraisal well which has encountered excellent reservoir as well as confirming the deep oil water contact at this location," Lundin CEO Ashley Heppenstall commented in a company statement.

According to the NPD, the 16/2-16 and 16/2-16A appraisal wells were drilling into Permian and Triassic rocks, with vertical depths of 7,175 feet and 6,760 feet respectively. These wells will now be permanently plugged and abandoned, while the Transocean Winner (DW semisub) rig that drilled them will proceed to production license 388 to drill wildcat well 16/1-17 – where Lundin is also the operator.

A former engineer, Jon is an award-winning editor who has covered the technology, engineering and energy sectors since the mid-1990s. Email Jon at jmainwaring@rigzone.com.

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Johan Sverdrup Appraisal Well Successful

Sweden's Lundin Petroleum and the Norwegian Petroleum Directorate (NPD) announced Friday that the 16/2-16AT2 appraisal well on the Johan Sverdrup discovery on production license 501 has been successfully completed.

The well was drilled as a side track to well 16/2-16 on the northeastern flank of the Johan Sverdrup field – approximately 0.6 miles to the west of the main bore hole. The objective of the side track was to improve the understanding of the lateral variations in reservoir qualities and relations to oil-water contacts in the neighboring wells.

Lundin (the operator, with a 40-percent interest) reported that the well encountered a gross oil column of approximately 98 feet with "largely excellent" reservoir quality within the Jurassic reservoir sequence. The acquired data also confirms an oil-water contact at approximately the same level as in well 16/2-10, which is the deepest observed at Johan Sverdrup.

"We are very pleased with the results of the latest appraisal well which has encountered excellent reservoir as well as confirming the deep oil water contact at this location," Lundin CEO Ashley Heppenstall commented in a company statement.

According to the NPD, the 16/2-16 and 16/2-16A appraisal wells were drilling into Permian and Triassic rocks, with vertical depths of 7,175 feet and 6,760 feet respectively. These wells will now be permanently plugged and abandoned, while the Transocean Winner (DW semisub) rig that drilled them will proceed to production license 388 to drill wildcat well 16/1-17 – where Lundin is also the operator.

A former engineer, Jon is an award-winning editor who has covered the technology, engineering and energy sectors since the mid-1990s. Email Jon at jmainwaring@rigzone.com.

For More Information on the Offshore Rig Fleet:
RigLogix can provide the information that you need about the offshore rig fleet, whether you need utilization and industry trends or detailed reports on future rig contracts. Subscribing to RigLogix will allow you to access dozens of prebuilt reports and build your own custom reports using hundreds of available data columns. For more information about a RigLogix subscription, visit http://www.riglogix.com/.

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