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Showing posts with label Nod. Show all posts
Showing posts with label Nod. Show all posts

Thursday, September 8, 2011

Apache Gets Environmental Nod for Julimar, Brunello Fields

- Apache Gets Environmental Nod for Julimar, Brunello Fields

Thursday, September 08, 2011
Apache Corp.

Apache said a subsidiary has received Australian government environmental approval for development of the Julimar and Brunello offshore natural gas fields that will supply natural gas to the Chevron-operated Wheatstone LNG project.

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Wednesday, August 31, 2011

GDF Suez Gets NPD Nod for North Sea Drilling

- GDF Suez Gets NPD Nod for North Sea Drilling

Wednesday, August 31, 2011
Norwegian Petroleum Directorate
by SubseaIQ

The Norwegian Petroleum Directorate has granted GDF Suez Norge AS a drilling permit for well 7124/4-1 S, cf. Section 8 of the Resource Management Regulations.

Well 7124/4-1 S will be drilled from the Aker Barents drilling facility at position 71°35'16.16" north and 24°5'56.84" east after completing the drilling of wildcat well 6508/1-2 for Det Norske Oljeselskap ASA in production license 482.

The drilling program for wellbore 7124/4-1 S relates to drilling a wildcat well in production license 530. GDF Suez Norge AS is the operator with a 30 percent ownership interest. The other licensees are Rocksource ASA (20 percent), Front Exploration AS (20 percent), North Energy ASA (20 percent) and Repsol Exploration Norge AS (10 percent).

The area in this license consists of the blocks 7123/6 and 7124/4. The well will be drilled about 100 kilometers north of Hammerfest and about 70 kilometers northeast of the Goliat field.

Production license 530 was awarded in the 20th licensing round. This is the first well to be drilled in the license.

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

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Wednesday, August 24, 2011

Sound Oil Gets Govt Nod for Rapagnano Concession

- Sound Oil Gets Govt Nod for Rapagnano Concession

Wednesday, August 24, 2011
Sound Oil plc

Sound Oil announced that the Italian Ministry for Economic Development has awarded the Rapagnano Concession, located in the Marche Region of central Italy, to the Company's wholly-owned subsidiary Apennine Energy srl. The award is subject to the acceptance of any environmental impact assessment that may be required by the Marche regional authorities. In view of the previous production history at the site which is within an industrial area, the Company anticipates that this acceptance will be granted.

The Rapagnano gas field on the concession had previously produced 4.1 Bscf of gas into the national network until it was shut-in in 2001. A recent reservoir engineering study by consultants Senergy (GB) Ltd has estimated that an additional 2.45 Bscf of gas is potentially recoverable from the field. Apennine's objective will be to put the field back on stream at an approximate estimated cost of US $0.5 million with expected first revenue in 2Q of 2012.

Commenting on the news, Gerry Orbell, Sound Oil's Chairman and Chief Executive, said, "This is very encouraging news. The Italian Ministry has awarded the Rapagnano field to us at no cost with the expectation that we can put it back on stream quickly. We intend to produce to the national gas network through the connection which is on site and provide an early cash flow with minimal investment."

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Thursday, August 18, 2011

BHP Billiton-Petrohawk Deal Gets Final Nod

- BHP Billiton-Petrohawk Deal Gets Final Nod

Thursday, August 18, 2011
BHP Billiton plc

BHP Billiton and Petrohawk announced that on August 17, 2011, BHP Billiton and Petrohawk received notice from the Committee on Foreign Investment in the U.S. (CFIUS) that CFIUS has concluded that there are no national security issues of concern in relation to the transactions contemplated by the merger agreement between BHP Billiton and Petrohawk, including BHP Billiton's tender offer for all of the issued and outstanding shares of common stock of Petrohawk for US $38.75 per share in cash. As previously announced, on July 22, 2011, BHP Billiton and Petrohawk received notice from the U.S. Federal Trade Commission of early termination of the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act in relation to the tender offer. Accordingly, all regulatory approvals conditions to the tender offer have been satisfied.

The documents related to the tender offer have been filed with the U.S. Securities and Exchange Commission (the SEC). As previously announced, the tender offer has been unanimously recommended by the Petrohawk board of directors and is being made pursuant to the merger agreement between BHP Billiton and Petrohawk. The tender offer is scheduled to expire at midnight, New York City time, at the end of Friday, August 19, 2011, unless the tender offer is extended or earlier terminated in accordance with the rules and regulations of the SEC and the merger agreement.

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Monday, July 25, 2011

RWE Dea Gets Govt Nod for Breagh Field Development

- RWE Dea Gets Govt Nod for Breagh Field Development

Monday, July 25, 2011
RWE Dea AG

RWE Dea UK announced that the field development plan for its operated Breagh gas field has received the unconditional approval of the Department of Energy and Climate Change (DECC) of the UK Government.

The FDP approval from DECC was formalized today by Charles Hendry MP, Minister of State for Energy at RWE Dea UK's London office, in a ceremony attended by senior management of RWE Dea and its Breagh license partner, Sterling Resources (UK).

"The FDP approval is a hugely significant achievement for our Breagh gas field development. It is an essential element for the realization of our strategic target to boost RWE Dea's annual gas and oil production to more than 70 million barrel of oil equivalents by 2016," said Ralf to Baben, Chief Operating Officer of RWE Dea AG.

René Pawel, RWE Dea UK's Managing Director, commented, "I am delighted with today's announcement by the UK Government. It means that RWE Dea UK remains on course to achieve production from the Breagh field less than three years after we acquired operatorship of the Breagh license."

The FDP approval marks yet another step in a busy summer for the Breagh development. Around 100 kilometers of 20" pipeline has been successfully installed offshore and the platform is due for installation in early September. The platform is being constructed by Heerema Vlissingen in the Netherlands and consists of a jacket approximately 85 meters tall with a total weight of some 4,000 tons and topsides of approximately 1,400 tons. The platform will be installed by Heerema Marine Contractors.

Energy Minister Charles Hendry said, "This is welcome news, Breagh is one of the largest natural gas discoveries in the Southern North Sea in recent years, and developments like this play a vital role in ensuring we have secure energy supplies throughout the UK. It is also encouraging to see the success of initiatives such as the Promote license, developed through PILOT, which originally allowed Sterling Resources to gain access to this acreage and bring the development forward under the partnership and operatorship of RWE Dea."

The Breagh field is located in UKCS blocks 42/12a and 42/13a of the southern North Sea in 62 meters water depth, approximately 100 kilometers east of Teesside. The field is being developed in two phases. Phase 1 entails gas to be exported via the 20" pipeline from the Breagh Alpha platform to Coatham Sands, Redcar on the UK mainland, and a 10 kilometers onshore pipeline for processing at the Teesside Gas Processing Plant (TGPP) at Seal Sands. The TGPP site is owned by Teesside Gas & Liquids Processing, and after processing at the TGPP, the gas will enter the UK National Transmission System. Phase 2, expected to receive FDP approval in early 2012, is expected to include additional wells in the east of the field drilled from a Breagh Bravo platform tied back to Alpha.

RWE Dea holds 70% interest in the Breagh gas field as operator (Sterling Resources UK 30%). The gas field is a conventional carboniferous reservoir and the expected reserves will make a significant contribution to the growth of RWE Dea's gas production. Further upside potential is expected in the surrounding exploration blocks.

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Thursday, June 9, 2011

Total: Ekofisk South, Eldfisk II Get Govt Nod for Development

- Total: Ekofisk South, Eldfisk II Get Govt Nod for Development

Thursday, June 09, 2011
Total

Total announced the launch of the Ekofisk South and Eldfisk II projects offshore in the southern Norwegian North Sea on Production Licence (PL) 018. Total holds a 39.90% interest in the license.

The plan for development and operation for each project has been approved by the Norwegian authorities.

The Ekofisk South project will include a new platform (Ekofisk 2/4Z) and a new subsea facility (Ekofisk 2/4VB) at the Ekofisk complex. The platform will have a 40 years design life and a capacity of 70,000 barrels of oil equivalent (boe) per day. The new facilities will enable the drilling of 35 production and 8 water injection wells to further develop the Ekofisk field and increase oil recovery. Production start-up is expected early 2014.

The Eldfisk II project will include a new platform (Eldfisk 2/7S) at the Eldfisk complex and substantially upgrade the existing facilities on the Eldfisk field. The new platform will have 40 years design life and a capacity of 70,000 boe per day. It will provide accommodation, new process facilities, and will enable the drilling of 30 production and 9 water injection wells to further develop the Eldfisk field and increase oil recovery. Production start-up is expected in 2015.

These two projects will enable the development of around 450 million barrels of oil equivalent of reserves.

"These two projects represent major investments for Total and clearly demonstrate our long-term commitment to continued value creation in Norway," said Patrice de Viviès, Senior Vice President Exploration & Production Northern Europe, Total.

The Ekofisk and Eldfisk fields were discovered in 1969 and 1970. First production was achieved from the Ekofisk field in 1971 and Eldfisk came on stream in 1979. The two fields produced around 260,000 boe per day on average in 2010.

PL 018 partners are Total (39.90%), ConocoPhillips (35.11% and Operator), ENI (12.39%), Statoil (7.60%) and Petoro (5.00%).

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Wednesday, June 8, 2011

Global Petroleum Gets Namibian Nod for Jupiter Acquisition

- Global Petroleum Gets Namibian Nod for Jupiter Acquisition

Wednesday, June 08, 2011
Global Petroleum Ltd.

Global Petroleum has received notification from the Namibian Competition Commission approving the acquisition of Jupiter Petroleum Limited by Global.

Under the sale and purchase agreement, Global will acquire Jupiter which holds prospective oil and gas exploration interests in offshore Namibia and in offshore Juan de Nova, a French dependency in the Mozambique Channel.

The sale and purchase agreement is conditional on the satisfaction of a number of conditions precedent, including due diligence investigations, obtaining necessary consents from governmental authorities, a report from an independent expert that the transaction is fair and reasonable to Global shareholders, and shareholder approval at a General Meeting.

As previously advised, consent for the transaction was required from the Namibian Competition Commission, and the Company is pleased that this requirement has been satisfied.

The Company is continuing to work towards satisfying the remaining conditions precedent as soon as possible and, subject to regulatory review, anticipates sending a Notice of Meeting to shareholders by the end of June.

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Wednesday, June 1, 2011

BHP Billiton Gets BOEMRE Nod for GOM Drilling

- BHP Billiton Gets BOEMRE Nod for GOM Drilling

Wednesday, June 01, 2011
BOEMRE

The Bureau of Ocean Energy Management, Regulation and Enforcement (BOEMRE) has approved a drilling permit for the fifteenth deepwater well to comply with rigorous new safety standards implemented in the wake of the Deepwater Horizon explosion and resulting oil spill. This includes satisfying the requirement to demonstrate the capacity to contain a subsea blowout.

The approved permit is for BHP Billiton Petroleum (GOM) Inc. to drill a new development well in Green Canyon Block 653 in 4,232 feet water depth, approximately 120 miles off the Louisiana shoreline, south of Houma. Today's approval is for a new well being drilled under a Development Operations Coordination Document that was approved on May 31, 2011, for which BOEMRE completed a site-specific Environmental Assessment.

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Monday, May 23, 2011

PUC Gives Nod to Eminent Domain Power for Pipeline Company

- PUC Gives Nod to Eminent Domain Power for Pipeline Company

Monday, May 23, 2011
Knight Ridder/Tribune Business News
by David Falchek, The Times-Tribune, Scranton, Pa.

The state Public Utility Commission intends to declare natural gas pipeline company Laser Northeast Gathering a public utility, giving it the power to condemn private property by eminent domain.

By a 3-2 vote, the commission tossed back to Administrative Law Judge Susan D. Colwell her recommendation to deny Laser's application for a "certificate of public convenience," which would grant it utility status and the right to wield eminent domain.

The narrow majority of the commission disagreed with Judge Colwell's arguments that the commission lacked the authority to regulate the activity and that Laser didn't meet the definition of a public utility.

Rejecting Judge Colwell's legal reasoning, the commission majority sent the recommendation back with a narrow charge: Determine if granting a certificate of public convenience is in the public interest.

In a fiery dissent, Commissioner James Cawley warned of "grave implications for individual Pennsylvanians and their communities." He said his colleagues' decision would upset the balance in easement negotiations, giving more power to pipeline companies.

"The upset of this balance is not in the public interest and is sufficient reason to deny Laser's application," Mr. Cawley wrote, joined in his opposition by Tyrone Christie.

Joining Mr. Gardner in remanding the Laser requests were Robert Powelson and John Coleman Jr.

Collection and gathering pipelines will directly impact more property owners than the gas wells expected to multiply over the next several decades tapping Marcellus Shale gas. Every well has an estimated lifespan of 30 to 40 years and has to be connected to an interstate pipeline.

Judge Colwell argued a pipeline collection and gathering system did not serve the "public," but rather natural gas well owners. But the commission said the legal definition of public "is not confined to the entire public," but rather the individuals or companies requiring the service.

Also at the meeting, Mr. Gardner said in his motion the PUC has the authority to enforce voluntary environmental safeguards to which Laser consented. Environmental group Earthjustice, which intervened in the case, said it is pleased the PUC recognized its ability to enforce those environmental protections reached in a side agreement with Laser.

"Gas development has proceeded at a frenzied pace in Pennsylvania and along with it has come countless spills, accidents, explosions," said Earthjustice attorney Megan Klein. "Finally, state officials have a chance to do something right from the outset, rather than rushing to clean up the aftermath."

But those protections in the Laser agreement may not be enforced across the board.

State Consumer Advocate Irwin "Sonny" Popowsky is concerned pipeline companies in Pennsylvania will continue to be free to opt in or opt out of regulation.

"At some point, the commission has to decide generically whether this activity of natural gas collection and gathering is going to be regulated as a utility activity or not," he said. "You can't just have companies deciding whether or not they get to be public utilities."

Based in South Abington Twp., Laser Northeast Gathering is run by former Southern Union executive Tom Karam. The company began building its 31-mile pipeline in February and plans complete it by the fall.

Copyright (c) 2011, The Times-Tribune, Scranton, Pa.

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Thursday, May 19, 2011

Sinopec Gets JDA Nod for Extension of Exploration Phase in Nigeria

- Sinopec Gets JDA Nod for Extension of Exploration Phase in Nigeria

Thursday, May 19, 2011
ERHC Energy Inc.

ERHC announced that the Nigeria-São Tomé & Príncipe Joint Development Authority (JDA) has approved a 12-month extension to Exploration Phase I Joint Development Zone (JDZ) Block 2. ERHC holds a 22 percent working interest in JDZ Block 2 which is operated by ERHC's technical partner, Sinopec Corp.

The JDA approval of extension is subject to final approval by the Nigeria-São Tomé & Príncipe Joint Ministerial Council.

ERHC's partner, Sinopec Corp., completed drilling of the Bomu-1 exploration well in Block 2 in October 2009. The well was drilled to a total depth of 3,580 meters, targeting 13 individual sands. Eight sands were found to contain biogenic methane gas. During the Exploration Phase I extension, the contracting parties led by the operator are expected to conduct further geological and geophysical studies on the Block. Further, they will assess exploration strategy and overall course of action regarding Exploration Phase II.

Negotiations on the exploration program in JDZ Blocks 3 and 4 continue between the JDA and the contracting parties, led by Addax Petroleum. ERHC holds 10 percent working interest in JDZ Block 3 and 19.5 percent working interest in JDZ Block 4.

In addition to its working interests in JDZ Blocks 2, 3 and 4, ERHC holds working interests in Blocks 5, 6 and 9 of the JDZ. ERHC also holds 100 percent working interests in Blocks 4 and 11 of the Sao Tome and Principe Exclusive Economic Zone (EEZ) with an option to acquire up to 15 percent working interests in two more Blocks in the EEZ.

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Friday, April 15, 2011

Statoil Gets NPD Nod for North Sea Drilling

Statoil Gets NPD Nod for North Sea Drilling

Friday, April 15, 2011
Norwegian Petroleum Directorate

The Norwegian Petroleum Directorate has granted a drilling permit for wellbore 6407/3-1 S, cf. Section 8 of the Resource Management Regulations.

Wellbore 6407/3-1 S will be drilled from the Transocean Leader drilling facility at position 64°46'32.49" N and 7°42'14.23" E after it has completed drilling of wildcat well 6407/4-2 for Statoil ASA in production license 429.

The drilling program for wellbore 6407/3-1 S relates to drilling of a wildcat well in production license 312 where Statoil ASA is the operator with an ownership interest of 59 percent. The other licensees are ExxonMobil Exploration & Production Norway AS (24 percent) and Eni Norge AS (17 percent). The area in this license consists of part of block 6407/3 and part of block 6407/6. The well will be drilled about six kilometers north of the Mikkel gas/condensate field.

Production license 312 was awarded on December 12, 2003 in APA 2003. This is the third well drilled in the license.

The permit is contingent upon the operator having secured all other permits and consents required by other authorities before the drilling starts.

Friday, April 8, 2011

OMV, Partners Get MED Nod for Seismic Acquisition at GSB

OMV, Partners Get MED Nod for Seismic Acquisition at GSB

Friday, April 08, 2011
OMV NZ Ltd.
OMV New Zealand and its Joint Venture partners have confirmed that applications to modify the current work commitments to include the acquisition of 3D seismic data and/or drilling in their Great South Basin exploration permits were approved by MED on March 25, 2011.
The number of commitments in each permit remains the same, as does the decision date for confirmation of the commitments.

"Allowing for either drilling and/or 3D seismic acquisition during the next phase of work gives us greater flexibility as we work through our next steps," Managing Director for OMV New Zealand, Dr Wayne Kirk explained.

"It’s important to note that very little was known about the Great South Basin geology when OMV and its Joint Venture partners were awarded the permits in July 2007."
Since then, the Joint Venture has acquired 16,000 km of 2D seismic data in 2008, plus an additional 2,600 km of 2D seismic data in 2010.

"We’ve now evaluated this data and believe that there are a number of prospective areas which may benefit from 3D seismic definition prior to drilling."

Dr Kirk reiterated that the Joint Venture continues working towards the July 10th decision date, but no final decisions over drilling, 3D seismic or individual license continuations have been made.

If the decision is made to commit to further work, the activity must occur by July 10th 2012.
The Great South Basin permits 50119, 50120 and 50121 are held by OMV NZ Ltd (Operator, 36%), PTTEP NZ Ltd (36%) and Mitsui E & P Australia Pty Ltd (28%).

Thursday, April 7, 2011

Buccaneer Gets ADEC Nod for Drilling Offshore Cook Inlet

Buccaneer Gets ADEC Nod for Drilling Offshore Cook Inlet

Thursday, April 07, 2011
Buccaneer Energy Ltd.

Buccaneer advised that the Alaska Department of Environmental Conservation ("ADEC") has reviewed Buccaneer's February 1, 2011 permit application for the offshore Cook Inlet Exploratory Drilling project and has issued a preliminary decision to approve the permit application.

As the Air Quality Permits are the longest lead time permits to obtain, taking a minimum 180 days, this milestone is an important step towards drilling the Company's offshore Cook Inlet projects.

The Company already held Air Quality Permits for two drilling locations in the offshore Cook Inlet, one at each of the Southern Cross Unit and North West Cook Inlet Unit. This application was in respect to an Air Quality Permit for an additional two drilling locations, one at each of the Southern Cross Unit and North West Cook Inlet Unit.

Extensive air modeling at each drilling location was required as part of the Air Quality Permitting process. This air modeling is required to assess the impact of emissions on the environment from a drilling rig and support vessels at the particular drilling location.
ADEC is now providing opportunity for a 30 day public comment period which expires on May 2, 2011.

Friday, April 1, 2011

Eni Gets BOEMRE Nod for GOM Drilling

Eni Gets BOEMRE Nod for GOM Drilling

Friday, April 01, 2011
BOEMRE

The Bureau of Ocean Energy Management, Regulation and Enforcement (BOEMRE) approved a deepwater permit for the drilling of an eighth well that complies with rigorous new safety standards implemented in the wake of the Deepwater Horizon explosion and resulting oil spill. This includes satisfying the requirement to demonstrate the capacity to contain a subsea blowout. The approved permit is a permit to sidetrack for ENI US Operating Co Inc.'s Well #SS001 in Mississippi Canyon Block 460 in 2,823 ft. water depth, approximately 57 miles southeast of Venice, La.

"This is the eighth deepwater well permitted to drill since February 17, when industry demonstrated that it had the capacity to handle subsea blowouts and spills," said BOEMRE Director Michael R. Bromwich. "The progress in permitting deepwater drilling is directly related to industry's ability to meet and satisfy the enhanced safety requirements associated with deepwater drilling, including the capability to contain a deepwater loss of well control and blowout."

ENI's Well #SS001 is a sidetrack well. A sidetrack well is drilled to a new geologic target or a new location within the original target from the existing wellbore. The operator had a rig on location when drilling preparation activities were halted due to the temporary drilling suspensions imposed following the Deepwater Horizon oil spill.

As part of its approval process, the bureau reviewed ENI's containment capability available for the specific well proposed in the permit application. ENI has contracted with the Helix Well Containment Group (HWCG)to use HWCG's capping stack to stop the flow of oil should a blowout occur. The capabilities of the capping stack meet the requirements that are specific to the characteristics of the proposed well.

BOEMRE has worked diligently to help industry adapt to and comply with new, rigorous safety practices. These standards ensure that oil and gas development continues, while also incorporating key lessons learned from the Deepwater Horizon oil spill. This new permit meets the new safety regulations and information requirements in Notices to Lessees (NTL) N06 and N10, and the Interim Final Safety Rule.