Sefton Makes Headway in California, Kansas

- Sefton Makes Headway in California, Kansas

Thursday, September 08, 2011
Sefton Resources Inc.

Sefton Resources announced an operational update on its most recent activities.

Highlights 

• Oil in California
  • Oil production rises to approximately 135 barrels per day during August.
  • Steam flooding pilot project sees oil production from Hartje #18 well boosted by 60% with increased reservoir pressure recorded at neighboring Yule #5 well.
  • Four wells planned for drilling during November at Tapia Canyon oil field.
  • A subsidiary of Occidental, the fourth largest US oil exploration company, has begun drilling the adjacent Wayside Canyon Oilfield, less than a mile away from Tapia Canyon. (Their field represents a virtual mirror image of Sefton's Tapia Canyon oil field only separated by a series of small faults).
• Gas in Kansas
  • Letter of intent signed to acquire a fourth gas pipeline plus adjacent wells and leases.
  • Agreement with Southern Star expected to be signed in late September to connect Sefton's pipelines from Leavenworth County to their interstate pipeline.
  • Significant progress with repairing the LAGGS pipeline system.
  • On going discussions with an exploration and production company which has significant acreage along the Vanguard pipeline for transportation of their gas through the Sefton pipeline system.
  • On going acreage acquisition program being developed based on the company's residual trend surface mapping techniques.

Commenting Thursday, Jim Ellerton, Executive Chairman said, "We are making good progress both in California and Kansas and now have in place a strong operational base, strong balance sheet and good cash flows from which to grow the business.

In California, oil production is rising on the back of steaming and we are looking forward to the publication of Dr Ali Farouq's report in October which will give us a clear indication of the potential and value of our interests in California as well as how to fully develop them.

In Kansas, 40-50% of Sefton's target areas for development in Leavenworth County and those in the surrounding areas remain underexplored due to a lack of activity over the past ten years. We believe this presents a significant opportunity for us."

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OMV Makes Gas Discovery in Norwegian Sea

- OMV Makes Gas Discovery in Norwegian Sea

Wednesday, August 31, 2011
Valiant Petroleum plc
by SubseaIQ

Valiant announced that drilling has completed on exploration well 6407/5-2S on PL471 located in the Norwegian Sea. The primary Chamonix target, a Cretaceous-age stratigraphic trap, was found to be dry having encountered poorly developed sands in the drill location. However, the well has made a small gas discovery in the secondary Cortina target having encountered a gross gas column of about 40 meters in the Upper and Middle Jurassic sandstones of the Rogn and Garn formations. An extensive data sampling program has been undertaken giving important information to de-risk similar nearby prospects. The discovery will be evaluated with the view to determine viability as a tie-back as part of a larger field development to surrounding infrastructure.

The well was drilled in a water depth of 230 meters using the semisubmersible rig Borgland Dolphin and was completed ahead of schedule and budget without any operational problems. The well has a deviated path and was terminated in the Lower Jurassic Tilje Formation at a vertical depth of 3359 m below sea surface. The partners in license PL471 are OMV Norge (50%, operator), Noreco (30%) and Valiant (20%).

Peter Buchanan, CEO, commented, "We are pleased to have made a small gas discovery on our first exploration well in Norway and we look forward to continuing to work together with our partners in order to fully evaluate its potential and the prospectivity of the rest of the license."

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Alberta Makes Concessions To Oil-Sands Producers In Parks Plan

- Alberta Makes Concessions To Oil-Sands Producers In Parks Plan

Tuesday, August 30, 2011
Dow Jones Newswires
CALGARY
by Edward Welsch

A final version of the Alberta government's land conservation plan for the oil-sands region released Monday made some concessions to oil companies after the original plan threatened to cancel parts of several oil-sands leases in order to preserve them for caribou habitat.

"What we think this plan achieves is a balance between the environment, development and the community aspect of living and working in Alberta," Sustainable Resource Development Minister Mel Knight said during a press conference.

Knight said there may still be parts of some oil-sands leases cancelled, but that the effect would be "very, very little," and the plan "is going to be quite satisfactory to most operators in the area."

The original parks plan released in April, which sets aside more than 7,000 square miles for recreational parks and wildlife including caribou, was panned by some of the oil-sands developers who were seeing parts of their leases cancelled.

However, most developers in the area, including Cenovus Energy Inc. (CVE) and Athabasca Oil Sands Corp. (ATH.T) said they had worked with the government to ensure that the parts of their leases that would be revoked were on plots that weren't economically viable.

Knight said the government worked with other companies to shift conservation land around for the final conservation plan, but he declined to provide any specific details.

Jennifer Grant, director of oil-sands research for the Canadian environmental think tank Pembina Institute, said it appeared that the government had shifted some lands around to accommodate oil-sands leases owned by Sunshine Oil Sands Ltd., a privately owned developer that was particularly hard hit under the draft plan.

Executives of Sunshine Oilsands, which is planning an initial public offering in Hong Kong later this year, weren't immediately available to comment because they were traveling in China.

"The government's efforts to accommodate industry interests are apparent in this version of the Lower Athabasca Regional Plan, with the adjustment of some protected areas," Grant said. She said more loopholes were introduced in the latest plan that allow companies to get exemptions to environmental standards.

Knight said though the plan had critics, it set aside a large portion of land for protection that wasn't there during the industry's last resource boom in the mid-2000s.
Copyright (c) 2011 Dow Jones & Company, Inc.

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Statoil Makes Gas Find in North Sea

- Statoil Makes Gas Find in North Sea

Monday, August 29, 2011
Norwegian Petroleum Directorate
by SubseaIQ

Statoil Petroleum AS, operator of production license 569, is in the process of completing the drilling of wildcat well 16/7-10. The well proved gas/condensate.

The well was drilled 16 kilometers northeast of the Sleipner Øst field in the North Sea.

The purpose of the well was to prove petroleum in Paleocene reservoir rocks (the Ty formation). Only a thin gas/condensate column was encountered in a 115-meter thick reservoir with the expected reservoir quality. The licensees will evaluate the discovery together with other nearby discoveries.

The well was not formation tested, but data acquisition and sampling have been carried out.

The well was drilled to a vertical depth of 2487 meters below the sea surface and was terminated in the Shetland group in the Upper Cretaceous. The well will now be permanently plugged and abandoned.

The well is the first exploration well in production license 569, which was awarded in APA 2010.

Well 16/-10 was drilled by the Ocean Vanguard drilling facility, which will now proceed to production license 120 in the northern part of the North Sea to drill production wells at the Visund Sør field, where Statoil Petroleum AS is the operator.

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Gulfsands Makes Oil Discovery in Syria

- Gulfsands Makes Oil Discovery in Syria

Friday, August 26, 2011
Gulfsands Petroleum plc

Gulfsands provided this update on operations in Syria.

Block 26 Drilling Operations

Yousefieh East Exploration Well (Yous-6)

The Yousefieh East exploration well ("Yous-6") has been drilled using the Crosco-E401 rig to test an undrilled structural high in Cretaceous age carbonates located approximately 3 kilometers to the east of the Yousefieh field discovery well (note, this well was erroneously referred to as Yousefieh-8 in a Gulfsands Petroleum plc News Release dated July 11th 2011). The Yous-6 well was deviated at an angle of up to 36 degrees to the vertical in order to avoid obstructions to drilling operations on the surface directly above the target location.

The Yous-6 well encountered oil bearing Cretaceous Massive Formation reservoir at a depth of 2045 meters Measured Depth Below Rotary Table ("m MDBRT") or 1560 meters True Vertical Depth Sub-Sea ("m TVDSS"), 28 meters deep to prognosis. The well penetrated the hydrocarbon bearing Massive reservoir section at an angle of approximately 29 degrees to the vertical. Two twelve meter core sections, parts of which were oil stained, were recovered from the wellbore over the interval 2055-2079m MDBRT (1569-1590m TVDSS). Interpretation of wireline logs indicates a gross porous reservoir interval of 18.1 meters was encountered overlying a non-porous interval, and having a net oil column of 12.8 meters, average porosity of 18% and average oil saturation of 69%.

Pressure data obtained via wireline logs indicates that the oil bearing reservoir is slightly depleted versus initial reservoir conditions, indicating that the Yousefieh East structure is likely to represent an eastern flank extension of the Yousefieh field which is currently on production at approximately 2,600 barrels of oil per day ("bopd"). Reservoir permeability in the Yous-6 net reservoir section is interpreted to be of similar quality to that encountered in the main producing areas of the Yousefieh field.

The Yous-6 well was production tested and produced at an average oil flow rate of approximately 250 bopd of 20 degree API oil for 4 hours on 2 inch choke under nitrogen assisted lift conditions with no water production. The well will be tested further following acidization of the reservoir in a rig-less operation.

Due to a thinner oil column encountered in this well versus other Yousefieh wells, the Yous-6 well will require the installation of permanent artificial lift facilities in order to flow continuously. The Yous-6 well is located within the Yousefieh field Development License Area and can be quickly tied back and produced into the existing Yousefieh field production facilities once artificial lift facilities are secured. Procurement of the relevant equipment is in progress.

The impact of Yous-6 on Yousefieh reserves will be evaluated as part of the year-end reserves review.

Safa-1 Exploration Well

Operations have been completed on the Safa-1 exploration well which was drilled using the Crosco M-501 rig. This well targeted a fault-bound dip closed structure of Cretaceous aged reservoir on trend and approximately 7 kilometers north of the Khurbet East Field.

The Safa-1 well is interpreted to have encountered the Cretaceous Shiranish Formation at 1937m MDBRT (1448m TVDSS) and the Cretaceous Massive Formation at 1953m MDBRT (1464m TVDSS). Three consecutive core sections were cut between 1942m and 1975m MDBRT (1453m and 1486m TVDSS), with a total recovery of 31.4 meters of core, sections of which were stained with viscous oil. Evaluation of wireline logs indicates a net reservoir interval of 9.9 meters with an average porosity of 13% and an average oil saturation of 74%.

Well testing operations were conducted in open hole over sections of the gross reservoir column in three stages, however only formation water of low salinity plus traces of viscous oil were recovered to surface, even after an acidification of the net reservoir interval was performed.

The Safa-1 exploration well therefore has been plugged and abandoned as a non-commercial heavy oil discovery.

Forward Drilling Program

Gulfsands drilling operations in Syria Block 26, using the Crosco E-401 and M-501 drilling rigs, will continue as planned with the drilling of one development and one exploration well.

The Khurbet East-20 well is planned as a delineation well to further evaluate the northern flank of the Khurbet East field. The Wardieh-1 exploration well will target a new exploration play, a combined structural/ stratigraphic trap located on the southern flank of the Souedieh Field at the Cretaceous "Massive" level.

Block 26 Oil Production

Production operations on Block 26 continue without interruption. Combined gross oil production from the Khurbet East and Yousefieh fields has averaged in excess of 24,000 bopd to date during the month of August following commissioning of an additional Khurbet East sub-station facility on August 6, 2011.

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Faroe Makes Oil Discovery West of Shetlands

- Faroe Makes Oil Discovery West of Shetlands

Wednesday, August 24, 2011
Faroe Petroleum plc

Faroe announced an oil discovery in its first operated exploration well on the Fulla prospect in the west of Shetland (Faroe Petroleum 50% and operator).

Highlights

• The 206/5a-3 exploration well discovers oil in the Fulla prospect
• The well penetrated a gross oil column in the well of 133 feet and a net oil column of 45 ft. Reservoir quality is better than expected.
• The oil has been sampled and details of the oil quality will be confirmed by further analysis conducted in the onshore laboratory.
• Faroe’s first operated exploration well has been successfully drilled in accordance with UK's HSE guidelines.

Well 206/5a-3 on the Fulla prospect was spudded on July 6, 2011 and was drilled to a total depth of 7,711 feet total vertical depth sub-sea (TVDSS) in 407 feet water depth. This Atlantic Margin well, located 31 kilometers to the north east of the BP-operated Clair field platform, was targeting potentially oil-bearing Clair and Whiting reservoir sands with the primary objectives of confirming hydrocarbons within the structure and, if present, running a comprehensive suite of wireline logs and obtaining representative oil samples.

The targeted reservoirs were encountered close to prognosis. The well drilled through a gross oil column of 133 feet and a net oil column of 45 ft. The average porosity in the net interval has been estimated at 23%. Oil samples were successfully recovered to allow detailed fluid analysis to be conducted in the onshore laboratory. Detailed data analysis will now commence on interpreting the results of this well, and subsequently, we will work to identify development options that include the Freya discovery made in 1980, which is located immediately to the south in the adjoining Block 206/10a (Faroe 50% and operator).

The Awilco-owned WilPhoenix semi-submersible drilling rig, which was used for the drilling operation, is now actively engaged in operations to plug and abandon the well as planned, and is expected to move away from the location in the coming days.

In December 2010, Faroe farmed out a 50% interest in this license to Canadian Overseas Petroleum Limited on promoted terms.

Graham Stewart, Chief Executive of Faroe Petroleum plc, commented, "We are very pleased with the positive outcome of this frontier West of Shetlands exploration well. To announce a discovery in our first operated well is a significant achievement for Faroe Petroleum and is a realization of the team’s vision and ability. Further work will be conducted in the coming weeks to gain a deeper understanding of the structure and its contents. With better than expected reservoir quality and good indications of mobile oil, we believe there is potential for a commercial field development, most likely in combination with our nearby Freya discovery.

"Faroe Petroleum applied for and won this license, which also contains the Freya discovery to the south, in the 22nd UK Licensing Round in 2005, and has worked continuously to de-risk this opportunity. This important new Fulla discovery is a great testament to the diligence and skill of our technical team.

"We look forward to three further exploration wells to be drilled in Norway this year. The Butch well with Centrica as operator is currently drilling, and we have two further wells, T-Rex and Kalvklumpen planned to commence in the coming months."

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Ivanhoe Makes Headway in Heavy Oil, Conventional O&G Projects

- Ivanhoe Makes Headway in Heavy Oil, Conventional O&G Project

Wednesday, August 10, 2011
Ivanhoe Energy Inc.

Ivanhoe reported financial results and operating highlights for the second quarter of 2011. Ivanhoe Energy has filed its quarterly financial report on Form 10-Q with the United States Securities and Exchange Commission and its Interim Financial Statements with the Canadian Securities Administrators for the period ended June 30, 2011.

Highlights

• In June the Company obtained broader and more extensive patent protection for its HTLTM intellectual property in Canada. This patent builds on and complements other issued and/or filed patents related to the core HTLTM technology and its petroleum applications. The portfolio includes the core patent, issued in the first quarter of 2011 related to the underlying HTLTM technology, which expires in 2028.
• The Company announced that heavy crude oil extracted from its IP-5B well in the Pungarayacu field in Block 20 in Ecuador was successfully upgraded to local pipeline specifications using the Company's proprietary HTL upgrading process.
• The Company issued Cdn$73.3 million of convertible unsecured subordinated debentures, maturing on June 30, 2016. A portion of the proceeds were used to repay a promissory note due to Talisman Energy Canada. The remaining balance of the funds raised will be used for ongoing capital and operating expenditures.
• Revenues were $9.5 million in the second quarter of 2011 compared to $6.1 million in the second quarter of 2010 due to a combination of stronger realized commodity prices and increased production. Higher volumes were allocated to Ivanhoe Energy for reimbursement of capital expenditures incurred at Dagang.
• In the second quarter of 2011, $6.5 million in cash flow was used in operations, consistent with $6.3 million of cash flow used in operations during the second quarter of 2010.
• The net loss for the second quarter of 2011 was $4.1 million compared to net income of $9.3 million for the second quarter of 2010, as a result of higher operating and general administrative expenses as well as lower non-cash foreign currency exchange and derivative instrument gains.
• General and administrative expenses were $11.7 million in the second quarter of 2011 compared with $9.1 million in the second quarter of 2010. The year-over-year increase stemmed from higher staff numbers associated with the Quito office build-out and our drilling operations in Sunwing, contract engineering work related to Ivanhoe's HTL technology and financing fees incurred in the recent Convertible Debentures issuance.
• The Company's cash and cash equivalents balance at June 30, 2011 was $133.3 million, which will be used to continue advancing Ivanhoe's ongoing projects in Canada, Ecuador, China and Mongolia.

"During the quarter we continued to prudently position Ivanhoe Energy to advance our heavy oil and conventional oil and gas projects," said President and Chief Operating Officer, David Dyck.

"In particular, the Company enhanced the intrinsic value of our heavy-to-light (HTL) upgrading technology by successfully testing it on Ecuadorian heavy crude and by securing patent protection to 2028 in key jurisdictions. We also put in place attractive new convertible debt financing to underwrite our operations and business development efforts."

Subsequent events

Zitong Block

Ivanhoe's wholly-owned subsidiary, Sunwing Energy, submitted the Provisional Overall Development Plan to the Joint Management Committee and PetroChina on June 30, 2011. As communicated in Ivanhoe's press release on June 15, 2011, this plan includes the acquisition of 3D seismic and the drilling of horizontal wells on the Block that will include multistage fracture stimulation. The Company is currently in discussions with PetroChina on final details of the Plan. This plan is to be conducted over the next 24 months.

Both the Yixin 2 and Zitong 1 wells have completed their respective long term built up tests and the down hole recorders have been recovered and the wells shut-in and secured. Data collected from these recorders has been delivered to contracted third-party tight gas experts to conduct detailed analysis and modeling of reservoir parameters and potential completion and stimulation techniques to assist the Company in developing exploitation programs on the Zitong Block.

Mongolia Block XVI

Sunwing is currently mobilizing the drilling equipment and supplies to N16-1E, its first exploratory drill site on Nyalga block XVI, which will be drilled on a structure approximately 32 sq km in size and to an approximate depth of 2500m. As of this date, the drilling rig is more than 75 percent assembled. Remaining minor drilling preparations will continue over the next few weeks, followed by the spud of Sunwing's first exploration well in Mongolia. Drilling of the well will take approximately 30 days, with completion and testing to be carried out as required. The Company intends to drill two wells initially, with the option to drill up to three additional wells, and remains optimistic of the potential to find oil resources in Mongolia.

Ecuador Seismic Program

As communicated in Ivanhoe's June 15, 2011 news release, Ivanhoe's wholly-owned Ecuadorian subsidiary commissioned a seismic program over the southern part of the Pungarayacu Block. The first phase of this program is now complete and analysis is still underway. Early interpretation is encouraging as it indicates deeper faulting, with the potential to trap lighter oil resources which could prove beneficial for blending purposes and overall project economics. Additionally, initial internal interpretations may also suggest an extension of the field beyond what was originally estimated.

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Total Makes Major Gas Find in Barents Sea

- Total Makes Major Gas Find in Barents Sea

Monday, August 08, 2011
Norwegian Petroleum Directorate

Total EP Norge AS, operator of production license 535, has completed the drilling of wildcat well 7225/3-1. The well, which proved gas, was drilled in the Barents Sea, about 250 kilometers north of Melkoya.

The primary exploration target for the well was to prove petroleum in Triassic reservoir rocks (Snadd and Kobbe formations). The secondary exploration target was to prove petroleum in the Middle Jurassic (Sto formation), Triassic (Havert formation) and Permian (Bjarmeland formation).

Gas was proven both in intervals from the Jurassic and the Triassic: in the Kobbe formation with a 400-meter interval in rocks of varying reservoir quality, and in the Havert formation in two intervals of 80 and 90 meters, respectively, in poorly developed reservoir rocks. Gas was also encountered in the Sto and Snadd formations.

Preliminary estimates place the size of the discovery between 10 and 50 billion standard cubic meters (Sm3) of recoverable gas.

A successful formation test has been carried out in the upper part of the Kobbe formation. The maximum production rate was 180 000 Sm3 gas per flow day through a 44/64-inch nozzle. The gas contains only small amounts of CO2, H2S and N2. The results from the well will be included in the ongoing evaluation of "Norvarg" to establish the size and extent of the gas discoveries.

The well was drilled in 376 meters of water and is the first exploration well in production license 535. The license was awarded in the 20th licensing round in 2009.

The well was drilled to a vertical depth of 4150 meters below the sea surface, and was terminated in the Orn formation in Permian rocks. The well will now be permanently plugged and abandoned.

Well 7225/3-1 was drilled by West Phoenix, which will now go on to drill for Statoil Petroleum AS on the Troll field in the North Sea.

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Endeavour Makes Headway in US, UK in 2Q11

- Endeavour Makes Headway in US, UK in 2Q11

Wednesday, August 03, 2011
Endeavour International Corp.

Endeavour reported adjusted EBITDA for the second quarter of 2011 was $7.6 million compared to $13.1 million in the second quarter of 2010 and $4.1 million in the first quarter of 2011. On a GAAP basis, net loss was $15.6 million for the second quarter of 2011 as compared to net income of $0.6 million for the same quarter in 2010.

Business Highlights:

• North Sea:
  • Commenced drilling operations at Bacchus
  • Agreement of commercial terms for the processing and transportation of the Greater Rochelle production on the Scott Platform
  • Contracts awarded for the pipeline and umbilical's for the development of Greater Rochelle area
• U.S. Onshore:
  • Announced the acquisition of 50,000 net acres in Marcellus Shale with existing production and pipeline infrastructure
  • 8 gross wells brought on production through July in Louisiana and East Texas
  • 4 additional gross wells completing or drilling in Louisiana
• Financial:
  • Increased available capital in July resulting in cash on hand of approximately $245 million

"During the second quarter financial results were as expected, while we made substantive progress on our U.K. development projects and our U.S. Haynesville unconventional gas play. Adding to this progress, our announced strategic acquisition of acreage and infrastructure gives us exposure to 1.0 to 1.3 trillion cubic feet of gross recoverable natural gas resource potential in the Marcellus area. We are confident that the balanced portfolio can deliver significant growth in both oil and natural gas production in the near-term," said William L. Transier, chairman, chief executive officer and president. "During July, the Company enhanced its flexibility and growth potential by adding approximately $100 million in available liquidity in addition to funding the $110 million needed for the Marcellus acquisition. The additional capital provides the resources to take advantage of opportunities for growth from existing and emerging parts of our portfolios, while also providing liquidity in case of any unforeseen events."

Operational Update

North Sea

The drilling of the three planned development wells is underway in the Bacchus field in Block 22/06a in the Central North Sea. Production from the development is expected to begin in the fourth quarter. The Company has a 30% working interest in the field.

In the Greater Rochelle area, the Company awarded two contracts for the design and fabrication of components for the subsea development that will link production for processing and transport to the nearby Scott platform. The contract for the drilling rig for the development will be finalized during the third quarter. Endeavour is operator and holds a 44% ownership interest in the Greater Rochelle development which is now comprised of Blocks 15/26b, 15/26c and 15/27.

U.S. Onshore

Endeavour will assume operated interests in leasehold, producing wells, pipeline and related facilities held by SM Energy Company and its minority partners in McKean and Potter Counties. The transaction increases Endeavour's leasehold interest in the Marcellus shale to approximately 93,000 gross (68,000 net) acres with more than 300 identified drilling locations in McKean and Cameron counties alone. The purchase will strengthen the Company's position in one of the most active and low-cost U.S. shale plays and provides significant production and reserve potential. The transaction is expected to close in the fourth quarter. In the Company's existing Marcellus acreage in Cameron County, two horizontal wells are waiting on completion, while the existing Daniel Field gathering infrastructure is being expanded.

During the quarter, Endeavour brought six gross wells on production in its Haynesville and Cotton Valley plays in Louisiana and East Texas, respectively. In July, production commenced from two additional gross wells with four other wells currently completing or drilling.

In the Montana Heath shale oil play, the Company and its partners expect to launch drilling operations on four vertical wells in the third quarter. In the Alabama Devonian shale gas play, Endeavour has successfully drilled and cased a horizontal re-entry of a previously drilled vertical pilot well. This well is anticipated to be completed and tested by the fourth quarter.

Financing Update

During the second quarter, the Company completed the redemption of all of its outstanding $81.25 million of 6% Senior Notes due 2012. The Notes were exchanged at 100% of principal amount plus accrued and unpaid interest.

In July, Endeavour closed on its private placement of $135 million aggregate principal amount of 5.5% convertible senior notes due 2016, including the full exercise by the initial purchasers of their option to purchase an additional $15 million principal amount of the offering. The Company intends to use the net proceeds of the offering primarily to fund its announced acquisition of operated interest in the Pennsylvania Marcellus shale play. Endeavour also expanded its credit facility by $75 million under the terms of its Senior Term Loan.

In addition, the Company entered into a letter of credit facility agreement with Commonwealth Bank of Australia in the amount of pounds Sterling 20,600,000 (approximately $33 million). Associated with the letters of credit was the release of the restrictions on approximately $33 million of cash.

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Beach Makes Oil Discovery at AU Western Flank

- Beach Makes Oil Discovery at AU Western Flank

Monday, August 01, 2011
Beach Energy Ltd.

Beach Energy announced two new field oil discoveries at Bauer-1, the third successful well in a five well exploration drilling campaign in PEL 91, and at Rincon-1, the final exploration well of the initial eleven well program for PEL 92. The commencement of the FY12 Joint Venture approved nine well exploration and development program, set down for PEL 92, will now follow this program.

The Bauer-1 well (Beach (Operator) - 40%, Drillsearch Energy Ltd - 60%) encountered a gross oil column of fifteen meters, with thirteen meters of net pay, in the McKinlay/Namur Sandstone section of the well. Preliminary volumetric assessment indicates the potential of the discovery could be in the order of two million barrels of recoverable oil (gross).

Following the completion of the evaluation program, the Ensign#18 rig will be moved to the Searcy-1 exploration well which is located approximately eight and a half kilometers to the north-east of Bauer-1. Bauer-1 is expected to be on-line in the fourth quarter of 2011.

The Rincon-1 well (Beach (Operator) - 75%, Cooper Energy Ltd - 25%) encountered a gross oil column of five meters, with four and a half meters of net pay, in the McKinlay/Namur Sandstone section of the well. Beach’s preliminary volumetric assessment suggests up to five hundred thousand barrels of recoverable oil (gross).

Following the completion of the evaluation program, the Ensign#30 rig will be moved to the Elliston-1 exploration well which is located approximately 25 kilometers to the south of Rincon-1. Options to bring Rincon-1 on-line are currently being assessed.

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Coastal Makes Oil Find Offshore Thailand

- Coastal Makes Oil Find Offshore Thailand

Friday, July 29, 2011
Coastal Energy Co.

Coastal Energy announced the successful results of the first exploration well drilled at Songkhla H and the results of initial production testing on the Bua Ban North B-06 and B-08 wells.

The Songkhla H-01 well was drilled to a total depth of 9,256 feet TVD and encountered 32 feet of net pay with 20 percent porosity in the Oligocene interval. A drill stem test was performed and the well produced 1,000 bopd with minimal initial pressure drawdown of the reservoir. The crude has an API gravity of 29 degrees. The H-01 well has the potential to produce in excess of 3,000 bopd using an electric submersible pump ("ESP"). The Company has spudded an appraisal well to delineate the reservoir.

The Bua Ban North B-06 and B-08 wells have been completed using ESPs and are producing approximately 2,000 bopd each from the Miocene interval. Flow rates will be restricted to these levels to minimize drawdown on the formation. The crude has API gravity of 29 degrees and is of quality consistent with current production. The Company is currently completing the B-01 well in the Oligocene formation. The B-06 well began producing on July 20th and the B-08 well began producing on July 27th.

Randy Bartley, Chief Executive Officer of Coastal Energy, commented, "We are extremely pleased with the results of both the Songkhla H-01 and the production testing at Bua Ban North B. The Songkhla H-01 well was drilled in the center of the basin where sand risk is the highest. Encountering sand of this quality in the basin center is very encouraging and opens up significant additional exploration potential.

"The initial flow rates from the B-06 and B-08 wells are performing above our expectations. We are proud to announce that we have been able to bring the Bua Ban North B field on production less than three months after the initial discovery well was drilled."

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Eni Makes Gas Discovery Offshore Indonesia

- Eni Makes Gas Discovery Offshore Indonesia

Thursday, July 28, 2011
Eni S.p.A.

Eni has made a new hydrocarbon discovery offshore Indonesia. As the operator, Eni has successfully drilled an exploration well on the Jangkrik North East structure, located in the Muara Bakau block Kutei Basin, east of Kalimantan, 15 Km from the Jangkrik field.

The Jangkrik North East discovery represents a significant success in Eni's exploration efforts in the Kutei Basin and further confirms the high potential of its portfolio in the area. The Jangkrik North East NFW is located approximately 70 kilometers from the coast of Indonesia and has been drilled to 3633m at a water depth of 460m.

The well contains more than 60m of net gas pay in excellent quality reservoir sands of Pliocene and Miocene age. During the production test, the well produced high quality gas at a tubing constrained rate of 30.6 MMscfd.

Eni, through its Indonesian subsidiary, is the operator of Muara Bakau PSC with a 55% interest. GDF SUEZ holds the remaining 45% interest in the project.

Overall, in Indonesia, Eni holds working interests in thirteen blocks, and operates seven of them. The offshore activities are located in the Tarakan and Kutei Basins, offshore Kalimantan, north of Sumatra West Timor and West Papua. In the Kutei basin, Eni is also participating in the development of the significant gas reserves located in the Ganal and Rapak blocks.

Other activities are located in the Mahakam River Delta, East Kalimantan, where Eni has an equity production of approximately 20,000 boed and has recently been awarded an interest in Sanga Sanga CBM, a new coal-bed methane production sharing contract (PSC) through its operated joint venture affiliate VICO CBM Limited (Eni 50%, BP 50%). The Sanga Sanga project would be the first LNG plant in the world to be supplied by CBM.

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Magnum Hunter Makes Management Changes in Finance Dept.

- Magnum Hunter Makes Management Changes in Finance Dept.

Wednesday, July 27, 2011
Magnum Hunter Resources Corp.

Magnum Hunter announced several management changes in the Company's finance department. Victor Ponce de Leon is being transferred in a lateral position and will now work at two of the Company's wholly-owned subsidiaries, Eureka Hunter Pipeline, LLC and Energy Hunter Securities, LLC.

Mr. Ponce de Leon has over 15 years of experience in the energy sector, with the last two years having served as Vice President of Finance and Treasurer at Magnum Hunter. He has previous experience as an Investment Banker with Morgan Keegan and West LB, having worked on numerous energy related transactions, including structured and corporate financings, mergers and acquisitions and fairness opinions. Mr. Ponce de Leon has also worked as an equity research analyst covering the exploration and production sector for CIBC World markets, Credit Lyonnais and Jeffries & Co. He received a B.B.A. in Finance from the University of St. Thomas and a Certificate in Accounting from the University of Houston.

Additionally, the Company has promoted E. Gabe Scott to Assistant Vice President of Finance and Assistant Treasurer of the Company. Mr. Scott has been an employee of Magnum Hunter since January 2011. He has five years of corporate finance experience with increasing management responsibilities in the energy sector, having spent the last year as a Financial Analyst for the Company. His work related experience include four years in Senior Financial Analyst positions with an upstream energy company, an energy sector focused private equity firm and with a multinational global financial services provider. Mr. Scott was a full scholarship recipient and four year letterman in baseball at the University of Alabama receiving numerous honors and recognition such as serving as team co-captain for several years, being named an ESPN Academic All-American, recognized as the Outstanding Finance Undergraduate Student for two years, a Paul Bear Bryant Student Athlete of the Year Finalist in 2005, a National Collegiate Baseball Writers Association All-American in 2005, and a First Team All Southeastern Conference choice in 2005 amongst many other awards for both his academic and athletic achievements.

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Rocksource Makes Headway in 2011 Drilling Program

- Rocksource Makes Headway in 2011 Drilling Program

Wednesday, July 27, 2011
Rocksource ASA

Rocksource has now announced the drilling results from three of its five, 2011 exploration wells. Initial results show one discovery (Norvarg) and two dry holes at wells drilled to test unproven petroleum systems (Breiflabb and Kora). Wells four and five in the 2011 program are expected to spud in September.

Norvarg

In June Rocksource announced a gas discovery in the Norvarg prospect in the Barents Sea license PL 535, operated by Total E&P Norge AS. On Norvarg Rocksource's Electromagnetic (EM) technology successfully identified the stacked hydrocarbon reservoirs present within the structure. It is too early to conclude on flow rate characteristics; hence the partnership has decided to perform a production test to gather information about reservoir production properties. Well operations are still ongoing with the planned well test to commence shortly.The test results are expected in early August.

Breiflabb

Earlier in July Rocksource announced a dry well on the Breiflabb prospect in license PL 416 in the Norwegian part of the North Sea. The Breiflabb prospect was characterized by a weak EM anomaly and was estimated to have a pre drill chance of success of 44 percent. The false positive response (EM anomaly not associated with hydrocarbon) is believed to have come from deeper levels that were not penetrated by the well.

Kora

The Kora-1 well in offshore Senegal and Guinea Bissau was on July 27 announced as unsuccessful. The Kora prospect had an EM anomaly interpreted by Rocksource to be associated with hydrocarbons with an approximate 50 percent chance of success. The prospect was found dry and the strong EM anomaly is believed to have been caused by a combination of lithologies (rock types) which have combined to produce unusually high resistivity. Although these lithologies were not specifically predicted pre-drill, given the lack of well control in this frontier area it was accounted for in Rocksource's prospect risking. Rocksource recently farmed down half of its interest in AGC Profond receiving as an initial consideration, USD 28 million in promoted contribution towards past expenditure and the costs of the Kora-1 well.

Commenting on the drilling results so far Chief Technology Officer John Howell said, "The average chance of success in our 2011 drilling campaign is approximately 50 percent. When you drill five wells with 50 percent chance of success, you should expect two to three discoveries and two to three dry holes. Although we would have liked more discoveries early, we believe we can still deliver a successful drilling campaign and we are looking forward to the results from the two remaining wells this year, and to test the further potential in our extensive exploration portfolio in 2012 and beyond."



The final two wells in 2011, will test the Heilo (PL 530) and Phoenix (PL559) prospects on the NCS. Both are expected to spud in September. Both wells are within proven petroleum systems and are on trend with earlier oil discoveries.

Heilo

PL 530 which includes the Heilo prospect is located in the Barents Sea on trend with the Goliat discovery to the west and the Nucula discovery to the southeast. The license which is operated by GDF Suez was reported to be the most sought after block in the Norwegian 20th Licensing Round. Rocksource carries a mean volume estimate of 200 mill boe and a chance of success of approximately 50% for the Heilo prospect. A success in the initial target will trigger a sidetrack to allow further efficient appraisal of the structure.

Phoenix

PL 559 which includes the Phoenix prospect was Rocksource's highest priority application in the Norwegian APA 2009 license round and is located on the Nordland Ridge, immediately to the east of the Norne, Urd, Falk and Linerle fields. Prospectivity within the license consists of three main prospects and several leads. All three prospects have encouraging EM responses. Rocksource carries a mean volume estimate of 160 mill boe for the Phoenix prospect and a chance of success of approximately 50%.

In parallel with the ongoing drilling operations Rocksource is continuing to mature EM positive prospects towards drilling decisions, and expect to firm up wells for drilling in 2012 and beyond throughout the remainder of the year.

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Infamous Oil Forecasts that Failed & What Makes a More Solid Forecast

- Infamous Oil Forecasts that Failed & What Makes a More Solid Forecast

Tuesday, July 19, 2011
Rigzone Staff
by Barbara Saunders

Even before Colonel Edwin Drake confirmed a way to drill for crude oil in 1859, pundits were already active in predicting the future of oil. Some called it "Drake's Folly" and forecast that drilling was not the way to reach oh well.

Skeptics called America's first drilled oil well "Drake's Folly" and insisted that drilling was no way to reach . . . Oh well.

But oil prices are what draw the primary predictions nowadays, even though $100 per barrel oil is really nothing new. During the Civil War, for instance, the price of oil soared to about $115 per barrel when adjusted for inflation in 2010 dollars. In fact, until an extended period after World War II through about 1970, oil prices were anything but stable and were often above levels seen in the 1980s and 1990's even without inflation taken into account.

In real terms, or adjusted for inflation, oil prices hit the equivalent of $100 per barrel or more in 1861 and again in 1980.

This underscores how poorly oil prices tracked inflation in modern history and the importance of technology in keeping pace with supply, regardless of price. In fact, according to the Society of Petroleum Engineers (SPE,) during the extended periods of low prices after the price crash of 1986, a number of technological advances occurred that lowered finding and lifting costs. These included the polycrystalline carbon drill bit and the expanded use of horizontal drilling.

In terms of price predictions, one of the biggest boners occurred only a few years ago, when forecasters during the summer of 2008 were predicting that oil prices would remain at levels of $150 or higher for the foreseeable future. Then came the global financial meltdown and took oil prices along with it, with an oil price plunge to the $30's by the following winter ooops!

A similar prediction occurred during the 1980's. Following the supply panics of the late 1970's, many were predicting that oil would reach $100 per barrel in nominal, or pre-inflation terms, by or before mid-decade. However, no such thing happened. Consumers, in part, had responded by purchasing much smaller cars than in the past and prices ultimately cratered by mid-decade, into the single digits for some crude grades.

"Beware all forecasts that do not have a strong basis in quantifiable supply/demand trends.

The problem with these particular forecasts was that some were predicated on wishful thinking, primarily by traders, not sound market fundamentals. Beware all forecasts that do not have a strong basis in quantifiable supply/demand trends. Just because renewed tensions have erupted in the Middle East, for instance, does not mean that oil prices are destined to fly up. Some of what is touted as "forecasts" in news bulletins is really the hype of traders hoping to make headlines that will push prices up on the commodity futures markets. Such hype may work briefly, but invariably, when there's nothing backing a prediction, prices will drop back in short order.

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Niko Makes Oil Find at Qara Dagh Block

- Niko Makes Oil Find at Qara Dagh Block

Monday, July 11, 2011
Vast Exploration Inc.

Vast Exploration provided the following update on the Niko-operated Qara Dagh Block in the Kurdistan Region of Iraq.

Drilling of the Qara Dagh well has reached a total depth of 3,908 meters, has been log evaluated and, as previously reported, the well has been cased to 3,558 meters with a 7 inch casing string. The following intervals have been evaluated where the results to date are summarized below.

Open Hole Interval - Shiranish Formation

This interval from 3,558 meters to 3,908 meters was acidized and flowed light oil confirming an active hydrocarbon column. The interval achieved maximum production rate of 550 barrels of oil per day and 800 mscf/d of gas, although these rates were not sustained for the entire duration of the test. The oil produced is 48 degrees API with no H2S.

From the data interpretation, and the significant spike in observed well bore pressures before the drilling was stopped, it is believed that the well has potentially entered into the first 10 meters of the next reservoir, the Cretacous aged Kometan formation, which is one of the primary target zones previously identified. It is important to note that the Kometan formation is regionally known to be a naturally fractured reservoir which has produced significant quantities of oil.

Mr. Ahmed Said, President & CEO, commented, "We are pleased with the recovery of light oil from this section. Although the reservoir quality appears to be naturally tight, the establishment of an oil column is significant. The possibility of drilling deeper to further evaluate production potential of the Kometan formation is currently under consideration."

Shiranish / Tanjero Interval

Certain sections in this cased interval was perforated and then acidized. The well had intermittent flow of light oil. The maximum rates achieved were 400 barrels per day of 42 to 47 API oil and 520 mscf/d of gas confirming a second active hydrocarbon system with no H2S.

Current Status and Forward Plan

The operator, Niko Resources, is currently in the process of testing the Aalijii Formation which consists of thick sequence of turbidities sand and argillaceous shales. While drilling this section in July 2010, it was reported that an increase in fluorescence, gas readings and free light oil in the mud system was detected.

Further, there are ongoing discussions between the consortium group to possibly deepen the well up to an additional 250 meters, subsequent to the completion of the current testing program. The primary purpose would be to drill deeper to further evaluate the production potential of the proliferous Kometan formation, the zone immediately below the Shiranish formation. Confirmation of the possibility and technical capability of re-entering the well and drilling deeper is expected over the next few weeks.

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Petrobras Makes O&G Discoveries Offshore Brazil

- Petrobras Makes O&G Discoveries Offshore Brazil

Tuesday, July 05, 2011
Petrobras

Petrobras announces new discoveries of oil and gas in Espírito Santo Basin, within the Concession Area BM-ES-23, Block ES-M-525, totaling 3 discoveries in this concession.

These new discoveries are 115 km far from the coast of the State of Espírito Santo, at water depths of about 1,900 meters, and occurred during the drilling of wells 1-BRSA-939-ESS (1-ESS-199) and 1-BRSA-936D-ESS (1-ESS-200D), informally referred to as Pé-de-moleque and Quindim. Recently, another discovery found after the drilling of well 1-BRSA-926D-ESS (Brigadeiro) has been announced.

Petrobras is the operator of the consortium for exploration of Block BM-ES-23 (65%), further constituted by companies Shell Brasil Petróleo Ltda. (20%) and Inpex Petróleo Santos Ltda. (15%). The consortium will continue the activities referring to the Minimum Exploratory Program within the concession area.

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HWCG Makes Headway in Expanding Deepwater Capabilities

- HWCG Makes Headway in Expanding Deepwater Capabilities

Wednesday, June 29, 2011
Helix Well Containment Group

The Helix Well Containment Group (HWCG) announced that it is now capable to respond to a subsea well containment incident in water depths of up to 10,000 feet.

The consortium previously announced its intention to achieve this milestone by mid-summer, and has achieved this ahead of schedule. Previously, it had capabilities to operate in water depths of up to 8,000 feet.

HWCG is a consortium of 24 deepwater operators in the Gulf of Mexico that have come together with the common goal of expanding capabilities to quickly and comprehensively respond to subsea well incidents to protect employees, communities and the environment.

"Combining ultra-deep water depth capability with a 15,000 pounds per square inch-gauge (psig) intervention capping stack, the HWCG consortium has the technology, expertise and resources of a diverse group of companies to respond immediately in the unlikely event that a deepwater well's blowout preventer fails to operate as designed," said David Coatney, HWCG's Managing Director.

Coatney was recently named HWCG Managing Director in May. He has more than 35 years of experience in the oil and gas industry, both in the United States and overseas. In previous roles, Coatney has served as an international upstream oil and gas asset consultant, Vice President of Production for Swift Energy and in various management and engineering capacities for Marathon Oil Company, where he worked for 29 years.

Coatney has been integrally involved in emergency preparedness and response for more than 20 years. He has acted as an Incident Commander—both domestically and abroad—and has led many successful responses in operational, natural disaster, well control and civil unrest incidents.

"Dave's combined expertise in drilling, production, offshore operations and incident response will be a strong asset to HWCG," said John Weust, HWCG's Steering Committee Chair. "I am confident he will play a significant and positive role in the ongoing operations of HWCG, in addition to enhancing the group's position in responding to the future needs of the industry."

Coatney holds a Bachelor of Science degree in Petroleum Engineering from Louisiana State University. He is a member of the Society of Petroleum Engineers, the American Petroleum Institute and the Association of International Petroleum Negotiators.

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Oilex Makes Progress at Cambay Well

- Oilex Makes Progress at Cambay Well

Wednesday, June 22, 2011
Oilex Ltd.

Oilex advised that the Cambay-76H horizontal well was directionally drilled as planned to casing point at 1,595 meters.

• Report date: June 21, 2011
• Status: Preparing to drill 8 ½" hole
• Past Week's Operations: 
  • Drilled 12 ¼" hole from 601 meters to 1,595 meters
  • Set 9 ⅝" casing to 1,594 meters
  • Tested BOP
• Objectives: Cambay Eocene "tight" reservoir Y Zone
• Kick off point for deviation: Approximately 1,100 meters
• Planned Total Depth (TD): Approximately 2,885 meters
• Days to TD: Approximately 35 days on a trouble free basis

Cambay Eocene Tight Reservoirs

The Company is making progress in unlocking the potential of the Cambay "tight" Eocene reservoirs that extend across the 161 km2 Cambay Production Sharing Contract ("PSC") area in onshore Gujarat, India. The Company intends to evaluate and exploit these reservoirs using horizontal drilling and fracture stimulation technology that has been developed and proven in North America.

The Cambay-76H "proof of concept" horizontal well will evaluate the production potential of the Y Zone interval of these "tight" reservoirs. An 8 stage fracture stimulation program will be conducted and after well clean-up, it is anticipated that a long term production test will be performed to determine flow rates, quality of hydrocarbons and commercial viability.

The participating interests in the Cambay PSC are:

• Oilex Ltd (Operator) 30%
• Oilex NL Holdings (India) Limited 15%
• Gujarat State Petroleum Corporation Ltd 55%

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Total Makes Gas Discovery in Barents Sea

- Total Makes Gas Discovery in Barents Sea

Thursday, June 16, 2011
Det norske oljeselskap ASA

Det norske has as license partner made a gas discovery in the Norvarg prospect in the Barents Sea license 535, operated by Total E&P Norge AS.

Exploration well 7225/3-1 has not been completed. Preliminary well data indicate gas at three different levels, a significant part of it in the Kobbe formation.

It is too early to conclude on flow rate characteristics and potential commerciality; hence the partnership has decided to perform a production test to gather information about reservoir production properties.

The test is planned to be carried out after the well has been drilled to total depth at about 4100 meters. Drilling operations are expected to continue for several weeks. Due to the production test, it is expected that the well will take longer time to complete than previously anticipated.

License owners are:

• Total E&P Norge AS (operator 40%)
• Det norske oljeselskap ASA (20%)
• North Energy (20%)
• Rocksource (20%)

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