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Showing posts with label Prospect. Show all posts
Showing posts with label Prospect. Show all posts

Thursday, September 8, 2011

Rocksource Spins Bit at Phoenix Prospect

- Rocksource Spins Bit at Phoenix Prospect

Thursday, September 08, 2011
Rocksource ASA

Rocksource announced that the drilling rig Borgland Dolphin has commenced drilling on the Phoenix prospect in PL 559 in the Norwegian Sea.

The PL 559 partnership consists of Rocksource (Operator and 60 percent working interest), VNG (30 percent) and Skagen44 (10 percent).

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Noble to Drill Cyprus A Prospect in 4Q

- Noble to Drill Cyprus A Prospect in 4Q

Thursday, September 08, 2011
Rigzone Staff
by Karen Boman

Noble Energy will relocate one of three deepwater rigs it is operating in the eastern Mediterranean Sea to drill the Cyprus A prospect during this year's fourth quarter, said Noble Chairman and CEO Charles D. Davidson at the Barclays Capital 2011 CEO Energy Conference earlier this week.

Noble said its prospect offshore Cyprus is analogous to the structures it has drilled offshore Israel, and anticipates that prospects offshore Cyprus also will contain gas. Drilling offshore Cyprus is still risky, but they basically are the same system, said Davidson.

"The prospect is an important data point, could change the dynamics further on how gas is marketed in the eastern Mediterranean Sea," Davidson said. "In our view, they have some demand for natural gas, and the scale of the projects in Cyprus will far exceed demand there."

Noble and the Cyprus government signed a production sharing contract to launch exploration activities in the 324,000-hectar economic zone southeast of the island.

According to media reports, tensions have mounted between Cyprus and Turkey over the island nation's plans to begin oil and gas exploration in the eastern Mediterranean Sea. Greek Cypriots, who control Cyprus' internationally recognized government, and Turkish Cypriots are at odds over how revenue from oil and gas production will be shared. Turkey, which backs the Turkish Cypriots, said it would take action if exploration begins before the dispute can be resolved.

Noble operates approximately three million gross acres in the eastern Mediterranean, where is recently acquired additional 3D seismic data and has identified multiple prospects and leads.

The Tamar and Leviathan discoveries offshore Israel, which include 25 Tcf of gross mean resources, are the largest global deepwater gas discoveries made in the past decade. "With the discovery of Tamar, Israel became energy independent in terms of gas," said Davidson. "The discovery of Leviathan has turned Israel into a potential energy exporter."

The company is on track to commission the Tamar production facility in late 2012, with production set to begin in 2013. A rig is on location drilling development wells, and construction of the production platform is underway. The initial development phase calls for five subsea completions with 200 MMcfe/d to 250 MMcf/d per well, and process capacity expanded to 1 Bcf/d at existing onshore facility. Mari-B infrastructure will be utilized as part of this development phase. The Tamar discovery has a resource estimate of 8.4 Tcf.

Noble also is moving ahead with the Noa development, which includes a two-well tieback to the Mari-B facility. First production is expected in the second half of 2012, and will supplement Mari-B deliverability by 100 MMcf/d. Mari-B is nearing full operational reliability, with the Mari-B compression project finalized and second quarter demand up 40 percent from 2010.

"Our current production [in Israel] is extremely strong, with high demand in Israel for gas, with a very strong draw for supplies from Mari-B," Davidson said

Noble expects results in this year's third quarter from its appraisal work to further define the Leviathan resource, which is estimated to hold gross gas resources of 16 Tcf. The company will return to assess deeper stratigraphic sections of Leviathan and is evaluating development scenarios for the discovery, including domestic and export options.

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Monday, August 15, 2011

Nostra Terra Reaches Total Vertical Depth at Verde Prospect

- Nostra Terra Reaches Total Vertical Depth at Verde Prospect

Monday, August 15, 2011
Nostra Terra O&G Co. plc

Nostra Terra announced that the initial well in the Verde Prospect in south-eastern Colorado, has been drilled ahead of schedule to a total vertical depth of 5,300 feet.

Indications of productivity in drilling samples and electric logs were positive and the well has been recommended for completion.

Production casing will be run to total depth, followed by completion in the most optimal zone(s). NTOG will provide the first 30-day production figures as soon as these are available.

NTOG has a 16.25% working interest (WI) in the Verde prospect. Following evaluation of testing and potential production of the initial well, two or three further development wells (PUDs) could be drilled, in which Nostra Terra also has the right to participate.

Matt Lofgran, Chief Executive Officer of Nostra Terra, commented, "We're pleased with the progress made on this well ahead of schedule and hope to see further positive results on this prospect. As a company, our current prospects are fully-funded, with additional cash on hand for further acquisitions, allowing us to continue to grow, regardless of the state of the global economy or markets."

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Centrica Spins Bit at N. Sea Butch Prospect

- Centrica Spins Bit at N. Sea Butch Prospect

Monday, August 15, 2011
Faroe Petroleum plc

Faroe Petroleum announced that drilling has commenced on the Butch prospect (Faroe 15%) located in the Norwegian North Sea.

The Butch prospect (block 8/10) is situated in the Norwegian North Sea, some seven kilometers east of the Ula field, 10 kilometers north east of the Tambar field and some 20 kilometers north of the Gyda field. The prospect is a stratigraphic pinch-out trap resting on the side of a salt dome and the primary target is the upper Jurassic Ula Formation which is the producing reservoir in the Ula, Tambar and Gyda fields.

The drilling operation, to be undertaken by Centrica as operator using the Maersk Guardian drilling rig, is expected to be completed in 4Q 2011.

Licenses PL405 and 405BS containing the Butch prospect were awarded to the Company in the APA 2006 licensing round. The other equity holders in these licenses are Centrica 40% (operator), Suncor ASA 30%, Spring Energy Norway AS 15%. In March 2009 the Company assigned a 15% interest in these licenses to Spring Energy in return for a partial carry on the well.

Graham Stewart, Chief Executive of Faroe Petroleum, commented, "We are pleased to announce the spudding of the first of our three near term Norwegian exploration wells, part of our fully funded drilling program. The Butch prospect offers an exciting opportunity to test a good prospect in the Jurassic Ula Formation, which has proved so successful in the nearby Ula, Tambar and Gyda fields .

"Elsewhere in our portfolio, drilling is also ongoing on the Fulla prospect West of Shetland, which is our first operated well, and for which results are expected to be announced later this month."

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Thursday, August 11, 2011

Aurora Drills Ahead at Tx. Alwan West Prospect

- Aurora Drills Ahead at Tx. Alwan West Prospect

Thursday, August 11, 2011
Victory Energy Corp.

Victory, through its partnership with Aurora Energy Partners, announced that its Alwan West (#1 Goff Mineral Trust) prospect well was spud on August 2, 2011 and is currently drilling ahead at 5,097 feet.

Prior to reaching the proposed target depth of 7,100 feet, all three target sands (first Yegua, Frio and second Yegua) will be tested. All three sands are anticipated to be reached and tested in the coming days. These sands do not require a fracking procedure to be productive. Anticipated completion after a successful testing generally occurs in less than two weeks.

The lease area is surrounded on all sides by gas condensate production and a delivery pipeline is within 1,000 feet of the well.

Alwan West lies on strike between two Yegua fields, Lost Fork (one mile west) and AVO Grande (3,000 feet east). Lost Fork has produced over 42 BCF, while AVO Grande has produced 7 BCF of natural gas. Both of these fields are stratigraphic traps, as is the Alwan West prospect. This area produces from the Frio and Yegua (Oligocene) formations.

This prospect's potential reservoir covers an area of 175 acres and has a reserve potential of 8.5 billion cubic feet (BCF) of natural gas and 43.75 thousand barrels of gas condensate.

The reserve potential is based on 50 feet of reservoir sand, one million cubic feet per acre-foot of natural gas and five barrels per million cubic feet of gas condensate. These reserve estimates are for the first Yegua sand only, which is the primary objective, and do not include potential in the secondary objectives.

The Alwan West prospect is located in far western Wharton County, Texas, near the Jackson County line. Victory Energy acquired the prospect, which includes a 5 percent working interest (WI) and a 3.8 percent net revenue interest (NRI), from Miramar Petroleum, Inc. of Corpus Christi, Texas, who will be the operator and who also owns a significant working interest in the well.

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Monday, August 8, 2011

ATP Primes Bit for Shimshon Prospect Offshore Israel

- ATP Primes Bit for Shimshon Prospect Offshore Israel

Monday, August 08, 2011
ATP O&G Corp.

ATP O&G announced an operations update for its properties in the Gulf of Mexico, the North Sea and Offshore Israel. Company-wide production continues to be 24-25 MMBoe/d.

Clipper

ATP commenced well operations with the Diamond Ocean Victory drilling vessel at the Green Canyon (“GC”) Block 300 (“Clipper”) #2 ST#1 during the second quarter of 2011. In July 2011, ATP successfully completed and flow tested the well at 45.6 MMcf per day plus condensate of 4,656 Bbls per day. The well is scheduled to be placed on production in the middle of 2012 after completion of the pipeline and tie-back to existing infrastructure.

After completion of the GC #2 ST #1, the Diamond Ocean Victory will move to the GC #4 well, re-enter and sidetrack the well to the targeted oil zone. All required permit applications have been submitted to the BOEMRE.

ATP operates Clipper and presently owns a 100% working interest.

Gomez Hub

During June 2011, ATP completed and returned to production the Mississippi Canyon (“MC”) Block 711 #5 well bringing to six the number of wells producing at Gomez. The development drilling plan (“DOCD”) for MC 711 #9 and MC 711 #10 were deemed submitted to the BOEMRE on June 8, 2011. Upon approval of the DOCD and the well permits, ATP expects to commence drilling at MC 711 #9 and #10 with first production expected mid-2012. The exploration plan has also been submitted for MC Block 710, a block immediately adjacent to MC 711 which displays similar seismic and technical characteristics to MC Block 711. Original proved reserve estimates of the Gomez Hub accounted for 14.8 MMBoe. Since commencement of production through June 2011 the Gomez Hub has already produced gross volumes of 24.8 MMBoe (66% oil).

ATP operates the deepwater Gomez Hub, has a 100% working interest in MC 711, 710 and 755, a 75% working interest in MC 754 and owns 51% of the ATP Innovator through a partnership with GE.

Telemark Hub

The MC Block 941 A-1 (#3) continues to produce as expected from the commingled C and D sands. Since inception, October 2010 through June 2011, the well has produced gross volumes of 2.8 MMBoe (85% oil and 15% gas). Based on the strong performance of the #3 well to-date, ATP expects to recover from the #3 and #4 wells all of the reserves that were initially projected from the C and D sands. Current water production of approximately 950 barrels per day is from the D sand which is to be expected since the downdip well, originally drilled by Vastar, was wet. Water cut is expected to increase until the D sand in the well, which represents less than 2% of the total proved and probable reserves of the Telemark Hub, is depleted, at which time the D sand sleeve will be closed. The ATP Titan, the floating production facility that services the Telemark Hub, has the capacity to process 25,000 Bbls of oil/day, 50 MMcf of gas/day and 15,000 Bbls of water/day.

Currently the MC Block 941 A-2 (#4) well is being completed; productive intervals in the C and D sands have been perforated and independently frac-packed. All remaining permits to complete this well have been approved, and remaining operations include running tubing, reconfiguring to allow flow testing the well and turning the A-2 to sales. First sales from the MC Block 941 A-2 are expected in the third quarter.

The MC Block 942 #2 well, which is already drilled to approximately 12,000 feet, will be drilled to total depth upon approval of the drilling permit by the BOEMRE and following the completion of the MC Block 941 A-2 well. ATP plans to complete drilling the well in the fourth quarter and expects first production by year-end.

ATP operates the deepwater Telemark Hub with a 100% working interest and owns 100% of the ATP Titan and associated pipelines and infrastructure.

UK North Sea

During the second quarter, the work on the Octabuoy floating production facility continued in the shipyard. Hull construction is on schedule and completion is expected early in 2012. Platform topsides are under construction in China (the utility module) and the US (the processing module). Upon completion of the processing module it will be shipped to China to be joined with the utility module. The hull and topsides will then sail to Norway for final commissioning and on to the Cheviot field in the North Sea where production is expected to begin in 2014.

In addition to Cheviot, ATP is working on its Skipper and Blythe projects in the UK North Sea. At Skipper, an oil project, an appraisal well to test production rates is scheduled for next year. At Blythe, predominately a gas project, discussions are ongoing to determine the most economic offtake route for the gas from this field. Development at Blythe is expected to commence in 2013. Skipper is located in the central UK North Sea in water depths of approximately 300 feet. Blythe is located in the Southern Gas Basin in water depths of approximately 100 feet. ATP operates both Skipper and Blythe and has a 50% working interest ownership in each.

Israel Expansion

During June 2011, through its subsidiary ATP East Med B.V., ATP acquired interests in three deepwater licenses in the Mediterranean Sea offshore Israel. ATP will operate its licenses, Shimshon, Daniel East and Daniel West, with a working interest of 40%. In the Mediterranean Sea, ATP licenses relate to exploratory prospects where drilling has occurred nearby and hydrocarbons have been discovered by others. ATP capital investment in the Mediterranean Sea is expected to be minimal for the remainder of 2011 as ATP prepares its exploratory and development plans for drilling in 2012.

ATP East Med, as operator of the licenses, has assumed the drilling contract with Transocean Drilling Israel Ltd. for the Sedco Express drilling unit at the Shimshon location where it anticipates initial drilling during the second quarter 2012. ATP expects to spend between $24 and $29 million during 2012 related to the initial exploratory well on the Shimshon license for its 40% working interest.

ATP notes that Isramco Negev, its partner in Shimshon, on March 6, 2011 reported that it received an independent reservoir engineering evaluation from Lockwood & Associates estimating gross potential natural gas reserves at Shimshon. According to Isramco Negev, "Lockwood & Associates considers the calculated assessment of the total geological and geophysical exploration probability of success of 20 percent to be reasonable. Lockwood said its high estimate was for 3.4 TCF, the low estimate was 1.5 TCF and its best estimate was 2.3 TCF."

Additional information on the Daniel East and Daniel West licenses will be provided as drilling and exploration plans are approved. ATP East Med is also party to two other licenses in offshore Israel which are awaiting approval by the Israeli Ministry of National Infrastructure. ATP continues to evaluate acquiring other licenses in the Mediterranean Sea.

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Wednesday, August 3, 2011

Bering IDs New Prospect in Permian Basin

- Bering IDs New Prospect in Permian Basin

Wednesday, August 03, 2011
Bering Exploration Inc.

Bering has identified a new prospect through its exclusive partnership with Glaux Oil & Gas, LLC (Glaux) that covers 500,000 acres in the Permian Basin. This new prospect of approximately 640 acres has potential gross reserves of 950,000 barrels of oil and, based upon today's prices, equates to $88 million dollars of gross revenues or $3.50 per share. There is no guarantee that this prospect will be successful or that these numbers will be achieved due to production and/or price fluctuations. Bering is currently conducting its technical assessment and once satisfactorily completed will begin leasing the mineral rights. Bering expects to initially retain a100% working interest.

This prospect was the first identified as a result of its recently announced three year exclusive exploration agreement with Glaux for the development of numerous leads and prospects in approximately 500,000 gross acres in West Texas using a proprietary aeromagnetic survey. Once leased, Bering will use other advanced oil finding technologies such as telluric and seismic to identify well locations.

The Permian Basin is one of the largest and most active oil basins in the United States, with the entire basin accounting for approximately 19 percent of total U.S. oil production. The Permian Basin remains a significant oil-producing province and contains an estimated 30 Billion barrels of remaining mobile oil and has the biggest potential for additional oil production in the country, containing 29% of estimated future oil reserve growth. Through increased use of enhanced-recovery practices the Permian Basin can have a substantial impact on U.S. oil production.

"We are excited to have our initial prospect generated by Glaux and expect to begin the leasing phase later this month," stated Steven Plumb, VP of Finance of Bering. "Our exclusive relationship with Glaux has provided us with this quality prospect that has been identified using unique and exciting technologies."

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Monday, August 1, 2011

Bering to Participate in La. Prospect

- Bering to Participate in La. Prospect

Monday, August 01, 2011
Bering Exploration Inc.

Bering has entered into an agreement to participate in a prospect in southeast Louisiana. The initial well in the prospect will be drilled to a depth of approximately 7,500 feet to test the prospective zones in the Wilcox formation. This prospect has the potential for multiple wells and potential gross reserves of 500,000 barrels of oil. Bering will have a 10% working interest in this prospect.

"We are happy to be participating in a new prospect that has great upside potential and is expected to be drilled in the next two months," stated Steven Plumb, VP of Finance of Bering. "This prospect meets our criteria of participating in projects which provide the company the maximum amount of value with a minimal amount of risk, and if successful, will increase our shareholder value."

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Monday, July 25, 2011

Bering to Begin Drilling Ops at Tx. Prospect

- Bering to Begin Drilling Ops at Tx. Prospect

Monday, July 25, 2011
Bering Exploration Inc.

Bering will begin drilling operations this week on its South Texas prospect. Bering will re-enter an existing well bore and perforate the Yegua formation which was not originally targeted in this well. This approximate 500 acre prospect has multiple drilling locations and will target the Yegua and Frio formations at various depths and is estimated to have over $9 million in potential gross reserves based upon the current price of oil and gas and assuming all wells are drilled and successful. Bering will retain a 50% working interest in this prospect.

"The well bore that we are re-entering was initially drilled targeting a much deeper zone and was never tested for the Yegua and Frio zones that have historically been productive in this area," stated Steven Plumb, VP of Finance of Bering. "We have ordered the pipe and requested the production unit for Tuesday of this week. We expect to begin oil production in the next few weeks if our completion is successful."

Eagleford Update

Bering has elected to employ an additional unique radiometric technology to further delineate its previously announced Eagleford prospects. Bering believes this additional testing will further reduce its drilling risks and has put its Eagleford operations on hold until such testing can be completed.

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Monday, July 18, 2011

Rocksource Hits Dry Well at Breiflabb Prospect

- Rocksource Hits Dry Well at Breiflabb Prospect

Monday, July 18, 2011
Rocksource

Rocksource ASA announced today that the drilling rig Borgland Dolphin is in the process of completing drilling operations on the "Breiflabb" prospect, in licence PL 416 in the Norwegian part of the North Sea. The well did not encounter hydrocarbons. The well will be further reviewed in the upcoming quarterly presentation on August 17th.

The PL 416 partnership consists of E.ON Ruhrgas (Operator and 50 per cent working interest), Det norske oljeselskap (15 per cent) and Rocksource (35 per cent).

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Friday, July 15, 2011

Salmander Primes Bit for Cat Ba Prospect

- Salmander Primes Bit for Cat Ba Prospect

Friday, July 15, 2011
Salamander Energy plc


Salamander announced the completion of drilling operations on the Dao Ruang structure, Block L15/50, onshore Northeast Thailand.

The Dao Ruang-3 appraisal well ("DR-3") has been drilled to a total depth of 1,800 meters true vertical depth sub-sea in order to test the pre-Tertiary carbonate section on the northern flank of the Dao Ruang structure. The well intersected a number of zones of interest with associated gas shows and a full suite of wire-line logs have been acquired. Analysis of all available well data suggests that DR-3 would have limited potential as a producer from the current wellbore. Due to this, and wellbore stability reasons, a decision has been made not to flow test the well. The DR-3 well is currently in the process of being plugged and abandoned.

Meanwhile, in Vietnam, the Aquamarine Driller jack up rig that will be used to drill the Cat Ba-1X prospect in Block 101/100-04, Offshore Northern Vietnam, is due to imminently commence mobilization to the well site. The Cat Ba-1X well is expected to spud before the end of July 2011.

James Menzies, Chief Executive Officer of Salamander Energy, said, "Dao Ruang is clearly a very large, gas-bearing structure, though we have not been able to find effective reservoir. We will now use this recent well data, together with the new 3D seismic data acquired over the Sinphuhorm field, to further develop our understanding of the play and review our wider position in the Khorat basin.

Focus of the drilling program now moves to offshore Vietnam with Cat Ba, a 100 MMbbl oil prospect, expected to spud later this month."

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Tuesday, July 12, 2011

Max Petroleum Starts Drilling at East Kyzylzhar Prospect

- Max Petroleum Starts Drilling at East Kyzylzhar Prospect

Tuesday, July 12, 2011
Max Petroleum plc

Max Petroleum has commenced drilling the KZIE-1 exploration well on the East Kyzylzhar I prospect in Block E. Total depth of the well will be approximately 1,500 meters, targeting potential Jurassic and Triassic reservoirs.

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Monday, July 11, 2011

Elixir to Farm-Out Stake at N. Sea Tiger Prospect

- Elixir to Farm-Out Stake at N. Sea Tiger Prospect

Monday, July 11, 2011
Elixir Petroleum Ltd.

Elixir announced the conditional farm-out of an interest in Block 211/12b located in the Northern Sector of the UK North Sea.

Background

Elixir is currently 100% interest holder and operator of the Block 211/12b. Through the use of 3D seismic data analysis and Fluid Inclusion Stratigraphy studies, a significant Upper Jurassic aged oil prospect named Tiger has been identified in the Block.

The Tiger prospect is situated close to prolific fields including the BP operated, 900 million barrel Magnus Field, the Shell operated Penguin cluster, and the more recently developed Don West field. Each of these fields could provide existing local infrastructure for the export of hydrocarbons in the event of exploration success at Tiger.

The Tiger prospect is a direct analogue to the Magnus Field, which is located 5 kilometers to the West. All of the play components, being source, migration, trap, seal and reservoir have been demonstrated to work at Magnus. The most likely, unrisked recoverable resource for Tiger is estimated to be approximately 90 million barrels.

Farmout Terms

Elixir has executed a farmout agreement with a privately owned oil and gas explorer to acquire an 85% interest in the license and operatorship in consideration for carrying Elixir's 15% interest on a partially promoted basis through the drilling of a firm exploration well, and a contingent appraisal well.

The Exploration Carry also includes all costs associated with logging and flow testing, and should it be necessary, plugging and abandonment. The repayment of the non-promoted part of the Exploration Carry is recoverable by the Farminee from Elixir's share of oil production receipts from Tiger. The total cost of the firm and contingent wells and, in the event of a discovery, the expected testing program, is estimated to be approximately £30 million.

On completion of the farmout, the Farminee has also undertaken to pay to Elixir a substantial cash contribution towards back costs.

The Farminee is obliged to complete the drilling of the firm exploration well by no later than November 30, 2012. In the event this deadline is not achieved, Elixir will be entitled to the reassignment of the Farminee's interest in the licence and operatorship.

Optional Development Carry

Under the terms of the Farmout Agreement, Elixir has also been granted an option by the Farminee to be fully carried through the development phase of the project. If a commercially developable discovery is made, Elixir will be able to exercise the option to be
carried and will not be required to contribute towards the costs of the development of the field through to the commencement of production.

The cost to Elixir of exercising this option will involve the repayment of the costs carried, the reimbursement of the Farminee's financing costs and a premium calculated as a percentage of the carried costs. At Elixir's election, the Development Carry can either be repaid directly at the time of first oil, or can be recovered by the Farminee from Elixir's share of oil production receipts (in which instance an increased premium will be levied by the Farminee). The size of the development carry given a most likely development outcome would be in the order of £50 million.

Farminee and Conditions Precedent

The Farminee is a private company owned and run by a group of experienced oil and gas professionals and financiers who have previously owned and operated oil and gas assets. The Farminee is a new entrant to the UK North Sea, and therefore is required to obtain approval as a licensee and as an operator from the UK Secretary of State for Energy and Climate Change (DECC). The receipt of the approval of DECC to the assignment of the licence interest and the transfer of the operatorship to the Farminee are the only two conditions precedent to completion of the farmout.

An initial meeting between the Farminee and DECC has been held. The Farminee will be required to demonstrate to DECC technical and financial capability in order to secure DECC's approval. DECC guidelines indicate that the approval process is likely to take approximately three months to complete. Assuming DECC approvals are received, it is anticipated the Tiger exploration well will be spudded in the first half of 2012.

Comment

We are delighted to have secured a farmout of Tiger on compelling terms which will see Elixir carried on two wells, and in the event of a discovery, with the option of a full development carry through to first oil. This transaction will be the catalyst for near term drilling activity at Tiger, one of the largest as yet undrilled exploration targets in the UK North Sea, and provides Elixir with exposure to the possibility of a significant oil development project on a low risk, essentially fully carried basis.

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Thursday, July 7, 2011

Antrim to Farm-Out N. Sea Erne Prospect

- Antrim to Farm-Out N. Sea Erne Prospect

Thursday, July 07, 2011
Antrim Energy Inc.

Antrim has signed a Heads Of Agreement (HOA) to farm out a portion of its Erne Prospect located in the Greater Fyne Area in the Central North Sea.

Premier Oil UK Limited (Premier) has agreed to earn a 50% working interest in Antrim's 100% owned License P1875 by funding a promoted share of the costs to drill a well on the Erne Prospect on Block 21/29d. The well is expected to commence drilling in the third quarter of 2011 as part of the Greater Fyne Area drilling program announced by Antrim on March 28, 2011. A contract has been signed with AGR Well Management Limited to provide well project management and drilling services, including the provision of the WilPhoenix semi-submersible drilling rig, and a site survey has been completed.

The Erne Prospect is an Eocene Tay Formation oil prospect located between the Fyne and Guillemot NW fields at a drilling depth of approximately 6,000 feet. Erne is analogous to the Guillemot NW Field, which produces oil from the Eocene Tay Formation.

The Erne farmout is part of Antrim's strategy of managing risk and reducing cost while maintaining significant interest in its North Seas properties.

Assignment of the license interest to Premier will be subject to approval by the UK Department of Energy and Climate Change (DECC).

As previously announced on April 04, 2011, Antrim and Premier, along with First Oil Expro Limited, will also collaborate on the drilling of an appraisal well on the eastern flank of the Fyne Field, License P077 Block 21/28a. The East Fyne well is anticipated to be spud in 4Q 2011.

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Thursday, June 30, 2011

Tower Updates Namibia Prospect Potential

- Tower Updates Namibia Prospect Potential

Thursday, June 30, 2011
Tower Resources

Tower Resources plc has provided details of the outcome of a second detailed technical and economic evaluation of the 0010 Licence, located offshore Namibia. Tower has a 15% working interest in the Licence and is fully carried financially by Arcadia Expro Namibia (PTY) Ltd (“Arcadia”) through an initial exploration well and a contingent second well.

The Tower Board has now received an updated Competent Persons Report, compiled by Oilfield International Limited (OIL), over Licence 0010. The CPR update follows the interpretation of the high quality 3D seismic data acquired in 2010 over the primary drilling target "Delta". OIL conducted a detailed review of the “Delta” structure and calculated the Expected Monetary Values (EMV’s) of the prospects and leads identified. OIL also updated the EMV of two other structures, ”Alpha” and “Gamma” which were the subject of the previously reported June 2010 CPR on Licence 0010.

The main conclusions of the CPR are summarised below.

The Delta Maastrichtian prospect remains the principal target for an exploration well. Best estimate prospective resources (50% probability) have been estimated as follows:

In the event of volatile oil, gross recoverable resources amount to 2.2 billion barrels and 3.4 trillion scft of natural gas. Net figures for Tower are 317 million barrels and 484 billion scft of natural gas.

In the event of gas condensate, gross recoverable resources amount to 267 million barrels and 8.1 trillion scft of natural gas. Net figures for Tower are 38 million barrels and 1.15 trillion scft natural gas.

In the event of dry gas, gross recoverable resources amount to 20 million barrels and 8.2 trillion scft natural gas. Net figures for Tower are 3 million barrels and 1.17 trillion scft natural gas.

Gross un-risked prospective recoverable resources from the Delta Palaeocene supplementary prospect and the other Licence wide supplementary leads at the 50% probability level amounts to about 10 billion barrels and 15 trillion scft of gas for the volatile oil cases and 35 trillion scft in the case of predominantly gas.

OIL has calculated for the Licence net risked prospective resources to Tower as 150 million barrels oil and 719 billion scft natural gas (together ca 270 million barrels oil equivalent). More importantly, the corresponding numbers for the target Delta Maastrichtian prospect alone are 55 million barrels oil and 257 billion scft of natural gas (together ca 98 million barrels oil equivalent).

OIL has calculated an EMV for the prospective resources of Tower and, in just the Delta Maastrichtian prospect, an EMV of US$744 million has been calculated. The Board believe there is also a very high upside in the other Delta horizons.

OIL has determined that there are now two prospects at Delta. The Maastrichtian prospect has been confirmed and the Palaeocene lead has been upgraded to a prospect. There are now three supplementary leads within the Delta structure: the Upper Campanian; the Campanian “wedge”; and at a deeper Albian horizon. The Alpha Palaeocene and Gamma Palaeocene leads are separate structures and would be the subject of further 3-D seismic before drilling.

OIL has used the seismic data, the two Namibian wells on the block and regional data to evaluate the likelihood that the reservoirs would be predominantly light oil-bearing; gas condensate-bearing or dry gas-bearing. For Delta, OIL concludes probabilities of 50%, 40%; and 10% respectively. The Gamma and Alpha structures are rated 45%, 44% and 11% respectively.

OIL have engineered the most likely development approach and associated capital cost, operating cost and production profiles for each case together with currently traded oil and gas prices (gas into Europe), escalated to 2020 first production and beyond. They have calculated NPV 10% after-tax values on that basis for each case. Each has been valued on an independent standalone basis to avoid trying to determine economies of shared facilities.

The final step has been to estimate a geological chance of success (“GCOS”) for each structure. DeltaM has been assessed as having a 40% GCOS and DeltaP a 24% GCOS. The leads have a GCOS ranging between 10 and 20%. An economic confidence factor has then been applied to the geological COS’s to calculate the economic COS “ECOS” which is used in the determination of risked reserves and the EMV calculations. DeltaM has a 31% ECOS; DeltaP a 19% ECOS; and the leads between 8% and 12%.

The OIL review team included two geophysicists, a geologist and a petroleum engineer having a total of 125 years of experience as technical specialists in the oil and gas industry. In particular, two of them have considerable experience of South America where South Atlantic exploration is most advanced. The OIL assessment has been undertaken in compliance with the SPE Petroleum Resources Management System (SPE-PRMS). OIL has had access to all available data from the Licence and a wide variety of regional technical information. They reviewed the work undertaken by Arcadia and specialist consultants and where relevant, undertook technical analysis of their own to accommodate their own wide and relevant experience, particularly of the Brazilian basins, and any publicly available information. Interaction with Arcadia took place to understand their technical approach but the conclusions drawn are entirely those of OIL.

The first exploration well, currently anticipated at the end of Q1 2012, will test as many as five zones of interest including two prospects and three leads targeting a “best estimate” resource potential of an estimated 6-12 billion barrels of recoverable oil equivalent (gross) depending on whether the fluid is predominantly gas or oil respectively.

Peter Kingston, Chairman of Tower Resources plc, commented: “The comprehensive independent reassessment of the prospectivity of Namibia Licence 0010 has confirmed its potential as a world class group of oil and gas prospects. It is particularly encouraging that the 3-D seismic survey has substantially increased the reserve potential of the Delta structure and has led to an improvement in the chance of success with the first well. This well alone, still on schedule for the end of Q1 2012, will test a resource potential of significantly more than 5 billion barrels of oil equivalent.”

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Wednesday, June 29, 2011

Drilling Completed at Tunis Creek Prospect

- Drilling Completed at Tunis Creek Prospect

Wednesday, June 29, 2011
Victory Energy Corp.

Victory Energy, through its partnership with Aurora Energy Partners, announced the successful completion of its Tunis Creek Oil and Gas Prospect in Pecos County, Texas. The University "6" #1 Tunis Creek well was spud on April 22, 2011 and was completed in the Ellenburger formation on Friday, June 24, 2011.

Very preliminary testing of the Ellenburger formation indicates that oil reserves could exceed earlier estimates. Pre-drilling internal total prospect reserve estimates exceeded 500,000 barrels. These preliminary flow tests on the University "6" #1 Tunis Creek well were performed using its natural bottom-hole pressure and was limited to the lower 20 percent of the Ellenburger formation in the wellbore. Sustained flow tests to evaluate bottom-hole pressure and to develop optimal flow rates for this well should occur over the next thirty days. Storage tanks are scheduled to be installed this week with oil sales to market occurring shortly thereafter. Associated natural gas testing has not yet occurred. A natural gas delivery pipeline is nearby.

Based on the positive results of this first well and the previously identified multiple oil and gas pay zones above this producing formation, the company will immediately begin evaluating locations for a second well on the acreage. Several additional development wells may be drilled if production warrants. Field rules established by the State of Texas will determine the exact number of wells.

Robert Miranda, Victory Energy's chairman and CEO, stated, "These preliminary completion results are outstanding and offer the first sizable validation of our ability to use our extensive network of oil and gas contacts to deliver immediate value to our shareholders. Wells of this quality and with reserves of this size are not typically available to micro-cap companies like Victory Energy. The additional development drilling opportunities available on the Tunis acreage could afford us at least two additional years of drilling at this location."

Victory Energy, through its partnership with Aurora Energy Partners, holds a 5 percent working interest and a 3.75 percent net revenue interest in this oil focused prospect.

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Tuesday, June 28, 2011

E. On Spins Bit at Breiflabb Prospect

- E. On Spins Bit at Breiflabb Prospect

Tuesday, June 28, 2011
Rocksource ASA

Rocksource announced that the drilling rig Borgland Dolphin has commenced drilling on the Breiflabb prospect in PL 416 in the Norwegian part of the North Sea.

The PL 416 partnership consists of E.ON Ruhrgas (Operator and 50 percent working interest), Det norske oljeselskap (15 percent) and Rocksource (35 percent).

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Monday, June 27, 2011

Aroway Boosts Production at Peace River Arch Prospect

- Aroway Boosts Production at Peace River Arch Prospect

Monday, June 27, 2011
Aroway Energy Inc.

Aroway reported that the Company's first well of the 2011 drilling program has been on a stable production for 20 days and is producing oil, natural gas liquids and gas from the targeted Leduc formation. The well, which is located in Peace River Arch oil and gas exploration prospects, was placed on restricted flow rate in late May, and in early June the well began to produce oil. Based on the present well pressures and the operators' conservative production practises, the well is expected to stabilize at a rate of 400 boe/day, 200 boe/day net to Aroway. The oil produced from the well is produced and pipelined to a facility owned by the Company's Joint Venture Partner and well operator. Aroway is paying 50% of all costs associated with this well to earn a 50% interest in the well.

The Company also reports that total depth has been reached on the third well of the 2011 drilling program. The well encountered numerous potential hydrocarbon bearing zones in the Triassic deposits and based on the drilling logs, the well will be evaluated in each of the prospective zones. A 100 meter pipeline tie-in has begun and will be complete in the next week, and the well will be production tested directly into the pipeline. Aroway is paying 50% of all costs associated with this well to earn a 50% interest in the well.

Testing on the Company's second well of the 2011 drill program will commence as soon as the roads dry out as heavy rains have hit the area over the past week. We are confident the service rig will be on the location and testing will begin within the next 10 days.

Chris Cooper, President of Aroway commented, "We were quite confident that our first well of 2011 would end up as an oil well as soon as the gas cap was produced. We will have concrete Company production numbers in coming weeks which will bring us much closer to our year-end target of 600 boe/day."

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Monday, June 13, 2011

Cuba Oil Plans Raise Prospect of Changing U.S. Embargo

- Cuba Oil Plans Raise Prospect of Changing U.S. Embargo

Monday, June 13, 2011
Knight Ridder/Tribune Business News
by David Goodhue, The Reporter, Tavernier, Fla.

The potential for vast oil reserves off the coast of Cuba, and the possibility that drilling there could start by the beginning of fall, has some saying that the United States could end or soften its Cold War-era trade embargo on its neighbor to the south.

Rice University political science professor and Latin American expert Mark Jones said ending the 50-year-old embargo remains a political non-starter among Florida politicians who feel it would make them appear "soft," which would result in a backlash from anti-Castro Cuban-Americans and cost them elections.

But, he said, Americans' appetite for the embargo is weakening and younger generations of Cuban-Americans are finding it harder to justify continuing the punitive policy.

"In the past, that threat [from anti-Castro voters] was real, but in recent years it is increasingly hollow with the proportion of the Cuban-American population that strongly supports the embargo diminishing, both due to a softening of attitude and particularly to generational turnover," Jones said in an e-mail this week.

The gateway for the United States to end or weaken the embargo may be the giant oil rig, the Scarabeo 9, which could be on its way to the Florida Straits from a shipyard in Singapore any day now. The Spanish oil company RepSol is the first of several foreign energy companies scheduled to explore for oil in deep water 50 miles from Key West. Drilling could begin by September.

Blocked by embargo

The operation is worrisome to Floridians and those in other coastal states in large part because the trade embargo would make it difficult for the United States to lend equipment, manpower and expertise to the area should there be an oil spill like the BP DeepWater Horizon disaster that lasted for months in the spring and summer of 2010.

The Obama administration has signaled it wants to improve relations with Cuba's communist government. In a controversial move, President Barack Obama last year lifted some travel restrictions for Cuban-Americans visiting relatives and friends on the island. Going any further, however, could prove too politically risky. But if the Cuban half of the Straits becomes an oil-producing hub, lifting sanctions may make more sense and appear justified, Jones said.

"What the oil production angle allows the administration to do is present to Floridians a self-interested rationale for softening or ending the embargo; if we do not, there could be a BP-type catastrophe, and the presence of the embargo would adversely impact the ability to keep the spill from harming the Florida coast and fisheries," Jones said.

Lawmakers respond

But Sen. Bill Nelson, Florida's senior senator, said through spokesman Bryan Gulley that the U.S. government already has licenses in place that it could authorize to allow companies and others to provide assistance in a disaster situation.

Gulley added that Nelson would not support lifting or easing the embargo "unless it was tied to democratic reforms in the country, including free and open elections and the release of political prisoners."

Representatives for Sen. Marco Rubio, Florida's Republican senator, did not respond to interview requests for this report.

Rep. Ileana Ros-Lehtinen, South Florida's Republican congresswoman, remains steadfastly against granting any leeway to the Castro regime. Her office e-mailed a statement regarding the question of lifting the embargo that started, "I don't deal in hypotheticals, but in what is actually happening now."

"I favor maintaining the embargo until in Cuba there is free expression, multi-party elections, freedom for political prisoners and human rights are respected," she said.

Both Nelson and Ros-Lehtinen have introduced legislation in response to the Scarabeo 9 project that would punish companies that help Cuba in its energy-production endeavors. Nelson last month asked Secretary of State Hillary Rodham Clinton to apply diplomatic pressure on Spain to convince RepSol to abandon the project.

Attitude change

But Jones thinks a lot can happen in the next year or two, especially if RepSol finds a lot of oil. He said he expects the Obama administration to stay quiet on the embargo through the November 2012 presidential elections. But if Obama wins re-election and the straits prove to be rich with crude, Jones said to expect a ramped-up effort on Obama's part to end the embargo.

"During his second term, assuming substantial oil reserves are found and significant production begins in Cuban waters, I would expect him to amplify the administration's movement towards better relations with Cuba, a major component of which would be ending or limiting the scope of the embargo and setting up bilateral mechanisms by which to deal with any potential oil spill or related catastrophe," Jones wrote in an e-mail.

Lee Hunt, president of the International Association of Drilling Contractors, favors relaxing certain aspects of the embargo, especially when it comes to oil exploration. But he said there is still avid support for maintaining the embargo among many Floridians and an equally strong opposition toward drilling off the state's coast. These factors together place doubt on Jones' theory, he said.

"I don't think Floridians are so 'fuel hungry' as to concede a half century's ideology for a few barrels of oil," Hunt said.

He said he did agree that if any significant change happens in the United States' Cuban policy, it won't be until after the 2012 elections.

"However, we are continuing to work to create a narrow exception to the embargo for services required in the event of a spill, i.e. in U.S. interests in protecting its coast and environment," Hunt said.

Jorge Pinon, a former energy industry executive and current visiting research fellow at the Cuban Research Institute at Florida International University, said changes could be coming in the embargo, but only in terms of oil equipment and services. He agreed with Nelson that these exemptions would be given only in cases of emergency and could be made by the president issuing a "general license."

"Remember it is Congress, not even the president, who can get rid of the U.S. economic embargo against Cuba," Pinon said.

Copyright (c) 2011, The Reporter, Tavernier, Fla.

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Wednesday, June 8, 2011

Statoil Takes Slice in GOM Kakuna Prospect

- Statoil Takes Slice in GOM Kakuna Prospect

Wednesday, June 08, 2011
Statoil

Statoil has farmed into the Kakuna prospect located approximately 180 miles southwest of New Orleans in deepwater Gulf of Mexico.

"Our agreement is with a subsidiary of Nexen, and the partnership plans on drilling an exploration well on this attractive Miocene structure later this year," said Statoil Exploration North America senior vice president Erik Finnstrom.

A federal exploratory unit for Kakuna has been approved by the Bureau of Ocean Energy Management and Regulatory Enforcement (BOEMRE) in the United States. It encompasses Green Canyon blocks 416 (W ½), 460, 504, 505 (W ½), 548 and 549.

The BOEMRE has determined that the exploration plan for Kakuna is complete and is currently reviewing the application for drilling the well.

Provided all required permits are approved by the BOEMRE, operations on the well will commence in Green Canyon block 504 in the second half of 2011.

Statoil controls 27.5% of the prospect, and Nexen, who controls the remaining 72.5%, is the operator.

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