Venari Resources LLC (“Venari”), a deepwater oil exploration and production company in the Gulf of Mexico, announced today that it has acquired an additional seven percent working interest in the Shenandoah field on Walker Ridge Blocks 51, 52 and 53. The company also reported successful results from the Shenandoah #5 appraisal well.
Map courtesy: Venari Resources
The Shenandoah #5 well was drilled on Walker Ridge Block 51 in approximately 5,900 feet of water to a total depth of 31,100 feet. The well was drilled up-dip of the Shenandoah #2 appraisal well and was designed to confirm and extend reservoir boundaries. The well encountered over 1,000 net feet of high-quality oil pay in the Lower Tertiary Wilcox sands and extended the field further east. The next appraisal well, Shenandoah #6, is expected to spud later this year to further quantify the full resource potential of the field. Earlier this year, Venari increased its working interest in the Shenandoah Unit to 17% from 10%.
“With a high-quality reservoir and substantial net oil pay, the well results confirm Shenandoah to be a significant oil accumulation,” said Brian Reinsborough, President and Chief Executive Officer of Venari. “We are excited that we were able to increase our ownership in the field and continue building our relationship with Anadarko across this strategically important region.”
In partnership with Anadarko Petroleum Corporation, the operator of Shenandoah, Venari owns significant working interests in several exploration prospects proximate to the Shenandoah discovery.
Venari holds a 17% working interest in Shenandoah. Other co-owners are Anadarko Petroleum Corporation (NYSE: APC), as operator (33%), ConocoPhillips Company (NYSE: COP) (30%), and Cobalt International Energy, L.P. (NYSE: CIE) (20%).
Venari Resources, a privately held offshore exploration and production company founded in 2012 by deepwater E&P expert Brian Reinsborough, is focused on the prolific oil-prone subsalt region in the Gulf of Mexico’s deep waters. Since its formation, preeminent global investment firms led by Warburg Pincus, Kelso & Company, Temasek, and The Jordan Company have committed $2.4 billion of capital to Venari’s exploration program and development projects. Venari has built a large inventory of drillable prospects and leases in the Gulf of Mexico including the Shenandoah discovery in the Walker Ridge area, the Anchor discovery in Green Canyon and the Guadalupe discovery in Keathley Canyon. The Company is headquartered in Dallas and has an additional office location in Houston.
The USGS has assisted the Government of India in the discovery of large, highly enriched accumulations of natural gas hydrate in the Bay of Bengal. This is the first discovery of its kind in the Indian Ocean that has the potential to be producible.
Natural gas hydrates are a naturally occurring, ice-like combination of natural gas and water found in the world’s oceans and polar regions. The amount of gas within the world’s gas hydrate accumulations is estimated to greatly exceed the volume of all known conventional gas resources.
“Advances like the Bay of Bengal discovery will help unlock the global energy resource potential of gas hydrates as well help define the technology needed to safely produce them,” said Walter Guidroz, USGS Energy Resources Program coordinator. “The USGS is proud to have played a key role on this project in collaboration with our international partner, the Indian Government.”
The deepwater D/S Chikyu as deployed during NGHP-02 was designed by the Japanese government for international scientific drilling operations (photo courtesy JAMSTEC).
This discovery is the result of the most comprehensive gas hydrate field venture in the world to date, made up of scientists from India, Japan and the United States. The scientists conducted ocean drilling, conventional sediment coring, pressure coring, downhole logging and analytical activities to assess the geologic occurrence, regional context and characteristics of gas hydrate deposits in the offshore of India.
This research expedition, called the Indian National Gas Hydrate Program Expedition 02, is the second joint exploration for gas hydrate potential in the Indian Ocean. The first expedition, also a partnership between scientists from India and the United States, discovered gas hydrate accumulations, but in formations that are currently unlikely to be producible.
Although it is possible to produce natural gas from gas hydrates, there are significant technical challenges, depending on the location and type of formation. Previous studies have shown that gas hydrate at high concentrations in sand reservoirs is the type of occurrence that can be most easily produced with existing technologies.
As such, the second expedition focused the exploration and discovery of highly concentrated gas hydrate occurrences in sand reservoirs. The gas hydrate discovered during the second expedition are located in coarse-grained sand-rich depositional systems in the Krishna-Godavari Basin and is made up of a sand-rich, gas-hydrate-bearing fan and channel-levee gas hydrate prospects. The next steps for research will involve production testing in these sand reservoirs to determine if natural gas production is practical and economic.
“The results from this expedition mark a critical step forward to understanding the energy resource potential of gas hydrates,” said USGS Senior Scientist Tim Collett, who participated in the expedition. “The discovery of what we believe to be several of the largest and most concentrated gas hydrate accumulations yet found in the world will yield the geologic and engineering data needed to better understand the geologic controls on the occurrence of gas hydrate in nature and to assess the technologies needed to safely produce gas hydrates.”
The international team of scientists was led by the Oil and Natural Gas Corporation Limited of India on behalf of the Ministry of Petroleum and Natural Gas India, in cooperation with the USGS, the Japanese Drilling Company, and the Japan Agency for Marine-Earth Science and Technology. In addition, USGS is working closely with the National Institute of Advanced Industrial Science and Technology Japan on the analysis of pressure core samples collected from sand reservoirs with high gas hydrate concentrations.
The USGS has a globally recognized research program studying natural gas hydrates in deepwater and permafrost settings worldwide. USGS researchers focus on the potential of gas hydrates as an energy resource, the impact of climate change on gas hydrates, and seafloor stability issues. More information can be found about the study and other USGS energy research here.
In an effort to enhance the ability to detect and measure oil spills offshore, the Bureau of Safety and Environmental Enforcement (BSEE) and National Oceanic and Atmospheric Administration begian a study on July 21, of multiple remote sensing systems at BSEE’s Ohmsett facility. The three-phase study employs Ohmsett’s 660-feet long, 2.6 million gallon capacity saltwater test tank. Spill responders will be able to use the study results to better monitor and measure oil slicks and emulsions in the marine environment and in the process improve offshore spill response operations.
A rotorcraft, carrying visual and thermal infrared sensors, collects imagery of the oil on the Ohmsett tank. Photo courtesy: BSEE
In the study’s first phase, researchers will compare multiple remote sensing systems to determine how well each detects oil/water emulsion mixtures and measures oil thickness. The remote sensors will view emulsified oil in the Ohmsett tank from multiple angles, heights and through different mediums to validate sensor capabilities. Above the water, sensors on the “Ohmsett Bridge” will provide a close-up view of the water surface while a remotely-operated vehicle will provide an underwater view. Simultaneously, remote sensors mounted on an Unmanned Aerial Vehicle, a fixed-wing aircraft, and a helicopter will take measurements. Three satellites equipped with remote sensors will also pass overhead and provide space-based observations.
The study’s second phase, planned for late 2016, will allow the research team to measure sensor performance in an open water environment and compare that data to controlled conditions at the Ohmsett tank. Development of operational methods and procedures for processing and interpreting the capabilities of the sensors will occur in the third and final phase of the study.
The Bureau of Ocean Energy Management (BOEM) has notified companies holding oil and gas leases in federal waters that it is updating financial assurance and risk management requirements to ensure that U.S. taxpayers never have to pay for decommissioning and removing a company’s offshore production facilities.
BOEM’s Notice to Lessees and Operators (NTL) details improved procedures to determine a lessee’s ability to carry out its lease obligations -- primarily the decommissioning of Outer Continental Shelf (OCS) facilities -- and whether to require lessees to furnish additional financial assurance.
“BOEM’s goal is to modernize its approach to risk management in a way that better aligns with the realities of the industry and protects the U.S. government and taxpayers from risk in a manner that isn’t overly burdensome to the oil and gas industry,” said BOEM Director Abigail Ross Hopper. “By implementing these changes, we will create comprehensive procedures to decrease risks to taxpayers while providing industry flexibility to negotiate adaptive solutions and use tailored financial plans to meet their financial assurance requirements.”
All OCS leases require that when decommissioning, the company must remove all facilities and restore the site to its pre-lease state. Due in part to the industry’s move into deepwater areas in the Gulf of Mexico, decommissioning costs have risen significantly. Moreover, as existing infrastructure ages, larger companies are transferring older facilities to smaller or less experienced companies. Current estimated routine decommissioning liabilities in the OCS are approximately $40 billion.
The NTL replaces NTL No. 2008-N07 and provides updated procedures for requiring additional financial security for oil and gas or sulphur leases. The revised NTL will provide updated criteria for determining a lessee's ability to self-insure its OCS liabilities based on the lessee's financial capacity and financial strength. It also provides new methods and additional flexibility for lessees to meet their additional financial security requirements through a tailored plan. The guidance and clarification will apply to all BOEM regions and planning areas. In addition to lease holders, the NTL also applies to right of use and easement holders.
“BOEM’s financial assurance regulations need to take into account current industry practices,” Hopper said. “We must ensure the U.S. taxpayer never pays to decommission an OCS facility and that the environment is protected. Managing risk in the early stages of a lease will provide lessees negotiated solutions that improve business certainty and leverage existing company strengths.”
BOEM will work with all lessees, both large and smaller individual lessees, to develop an approach that works best for the government and for each company while focusing on the highest risk properties first. The intent is to examine each company individually, assess its total financial assurance needs and then work with the company to determine the best financial assurance instrument(s) for its individual needs. After today’s publication, BOEM is providing a 60-day grace period before the NTL is implemented.
BOEM will focus first on those properties that pose the highest risk to the government, namely, properties for which there is only one leaseholder responsible for decommissioning. Those leaseholders will have 60 days, from the date of an order requiring additional financial security, to comply.
Additionally, for all other holdings, lessees will have 120 days from the date they receive an order to provide additional security, if required.
Alternatively, lessees can provide a tailored financial plan to BOEM, which will permit the use of forms of financial security other than surety bonds and pledges of treasury securities and allow companies to phase in funding of the additional security.
BOEM has engaged in a significant amount of outreach since the announcement of the proposed guidance on September 22, 2015, holding a bonding workshop, a financial assurance forum and many meetings with individual companies and industry associations. BOEM extended the initial 45-day comment period by two weeks in response to industry’s request for additional time to provide comments. The updated guidance is within the parameters of BOEM’s existing regulations so it was not necessary to propose a new rule.
More information about the NTL can be found here.
The NTL is posted here.
Claxton, an Acteon company, has been awarded a contract with Statoil to provide ‘rigless recovery’ of seven abandoned wells on the Huldra platform, located in the Norwegian Continental Shelf.
The contract was finalized in July 2016, and work is scheduled to commence in December 2016 with the project due for completion within 21 days. Claxton is responsible for a full scope of decommissioning work including project planning, severance, and full multiple string recovery.
Photo credit: Statoil
Laura Claxton, managing director, Claxton, said, “Claxton performed the world’s first rigless platform well abandonment campaign on the Esmond, Forbes and Gordon field in the North Sea in 1995 and have completed more than 280 cutting and recovery projects since.
“This experience allows us now to provide the most comprehensive decommissioning packages for our clients. Being awarded this contract with Statoil reinforces our leading position in the decommissioning market and demonstrates that clients value our experience, strategic technical approach and capabilities.”
Conductor and casing severance for the Huldra project will be performed using the latest evolution Claxton recovery tower and its abrasive cutting system ‘SABRE’. The SABRE unit and all ancillary equipment are NORSOK compliant to Z-015, with the recovery tower having a safe working load of 300Te with a modular system footprint design that minimises rig-up time and complexity.
Rigless platform well abandonment is just one of the many services Claxton can offer to reduce the cost of your decommissioning project. Learn more about Claxton’s decommissioning services.
National Oilwell Varco, Inc. (NYSE: NOV) and GE Oil & Gas have announced the execution of an agreement to collaborate on delivering integrated solutions for Floating Production Storage and Offloading (FPSO) vessels. The agreement brings together the complementary product offerings and engineering capabilities from two industry leaders to optimize engineering design and supply comprehensive topside solutions for FPSO projects.
NOV engineers and manufactures advanced fluids pumping, treatment and processing systems; composite piping systems; cranes and deck machinery; and sophisticated, disconnectable turret mooring systems for FPSOs and related vessels. Additionally, NOV has successfully installed and commissioned equipment on hundreds of vessels in dozens of shipyards for the oil and gas drilling industry.
GE Oil & Gas engineers and manufactures advanced technology solutions for many of the world’s most complex power generation and gas compression projects. Also, with its Subsea Production Systems, GE Oil & Gas offers a comprehensive range of solutions including subsea trees, manifold & connection systems, and power & processing technology.
GE Oil & Gas may also involve other GE businesses in the collaboration with NOV.
The new, combined platform will provide industry-leading topside systems with repeatable deliveries, scale economies and standardized interfaces, which are expected to reduce risk of construction delays and cost overruns for deepwater oil and gas customers. Additionally, the new platform will incorporate digital solutions, which will optimize performance and provide predictive analytics through the life of the vessels, enabling FPSOs to efficiently adapt to a wider array of operating parameters.
The industrialized manufacturing supply chain, combined with digital solutions and global service and aftermarket capabilities, is expected to maximize life-cycle efficiencies and drive down the cost of offshore oilfield development.
NOV and GE Oil & Gas expect to complete joint engineering efforts and commence offering topside package solutions to the oil and gas industry by early 2017. “We can materially improve deepwater production economics by industrializing the supply chain and standardizing complex interfaces between our complementary topside equipment,” said Clay Williams, NOV’s Chairman, President and Chief Executive Officer. “For the past year we have quietly explored this new and better way to make floating production vessels and are excited about how this collaboration will change the industry and improve the economics of deepwater production development.”
“With this agreement, we are bringing together capabilities and expertise from GE Oil & Gas and NOV to better serve our customers and overcome oil and gas offshore industry challenges,” said Lorenzo Simonelli, President & CEO, GE Oil & Gas. “Digital solutions will add even more value to the agreement. Digitization has become not only a competitive differentiator but increasingly, a necessity to help our customers make their businesses stronger long-term.”
NOV and GE Oil & Gas remain independent suppliers of equipment, services and systems.
The Industry Technology Facilitator (ITF) has launched a new global online Innovation Network to raise the profile of oil and gas SMEs direct to its membership of operator and service companies.
Available here, the Innovation Network is an active online community enabling oil and gas SMEs to promote their technologies and services direct to end users and also keep up to date with the latest technology needs of the industry.
All technology organizations with less than 250 employees can post a free profile on the Innovation Network including a company description. Companies can also sign up for premium and elite subscriptions which offer a number of additional benefits from posting videos, case studies, available technologies and field trials to securing exhibition space at the annual Technology Showcase and receiving regular updates from ITF members.
Dr. Patrick O’Brien, CEO of ITF said: “The Innovation Network is a brand new platform to bring together our oil and gas membership with the SMEs that could potentially solve some of their costly challenges.
“It has been developed in direct response to a demand from technology companies seeking introductions to our end users and we have commitment from our membership that they want to engage in this way and see great value in getting tangible insights into the innovations coming from the SME community, particularly those that can be quickly implemented. This will be an active and evolving community where we will encourage discussion and engagement on field trials, joint industry projects and technologies that have high readiness levels.”
ITF, a not-for-profit organisation, has facilitated the launch of more than 200 projects from early stage concepts through to field trials and commercialisation.
ITF is driving oil and gas technology development and collaboration. With a membership of international oil and gas operator and service companies, the industry technology facilitator has launched over 200 innovative joint industry projects. ITF champions technology development and believes investment is crucial to solving the most pressing challenges the industry faces in securing reserves and maximising economic recovery.
Fugro is to commence a major program of offshore geotechnical investigations under a contract awarded by Indian oil and gas company, ONGC.
Fugro deploys deepwater geotechnical vessel, Fugro Voyager, for ONGC works offshore India’s east coast
Valued at approximately USD 26million, the contract involves site investigation work to gather geotechnical and geohazard data at the field, which is located in the KG-DWN-98/2 block off the east coast of India. The information will support the design and subsequent installation of wellheads, manifolds, platforms, FPSO anchors, umbilicals, pipelines and flow lines.
Fugro will deploy its deepwater geotechnical vessel, Fugro Voyager, which will perform the work in water depths ranging from 50 to 1,500 meters. The fieldwork will be followed by extensive laboratory testing, data analysis, interpretation and integration with other data acquired by Fugro.
Commenting on the work, which is due to commence before end of Q3, Fugro’s Jerry Paisley said, “Fugro has an extensive track record in supporting deepwater field developments offshore India. For the site characterisation reports for ONGC we will integrate the geotechnical and geohazard data from this project with metocean data and AUV geophysical survey data we acquired previously at this field.”
With roughly 70 percent of global production coming from mature fields, well intervention projects are quickly becoming a huge fiscal and operational opportunity for GOM operators as the slowing in drilling operations forces operators to look for new and innovative ways to efficiently increase production from their existing well stock.
Numbers show that the average worldwide recovery factor for oil is only 35%. To understand the implications, it is worth pointing out that a mere 1% recovery increase would be the equivalent of an additional two-year supply. However, the GOM average recovery for subsea assets is just 22%, while Statoil routinely deliver over 50% recovery in the North Sea through subsea well intervention. There is no reason GOM operators cannot achieve similar results, especially considering that in North America, production from new wells costs virtually twice as much as production from existing fields.
However if the GOM industry can come together to deliver technology improvements, address skill shortages with experienced intervention departments and develop contract models and costing that suit the GOM market, there is every chance that the intervention market will grow rapidly in the near future.
On October 19-20, key industry figures will come together at the 3rd Annual Offshore Well Intervention Conference in Houston to share case studies on critical projects and latest technical innovations to equip you with practical experience to take advantage of this expanding market sector:
Other speakers include Wild Well Control, Interwell, Schlumberger, Halliburton and many others. They will be joined by over 160 delegates including representatives from Chevron, BHP Billiton, W&T Offshore, Total and Stone Energy. Check out the full conference agenda at http://tinyurl.com/ON-OWI-Program
If you have any feedback or questions regarding the event, please contact Sam Scarpa on This email address is being protected from spambots. You need JavaScript enabled to view it..
Noble Energy, Inc. (NYSE: NBL) ("Noble Energy" or "the Company") announces that it has recently commenced production at the Company's Gunflint oil development in the deepwater Gulf of Mexico. The two-well field is ramping up and is anticipated to reach a minimum gross production of 20 thousand barrels of oil equivalent per day (MBoe/d), with oil representing approximately 75 percent of the volumes produced. The net amount to Noble Energy is expected to be at least 5 MBoe/d, with potential for additional volumes dependent upon available capacity at the third-party host facility. The Gunflint development, located at Mississippi Canyon Block 948, is a subsea tie-back to the Gulfstar One facility owned by Williams Partners L.P. and Marubeni Corporation.
Image courtesy: Noble Energy
Hodge Walker, Noble Energy's Vice President, Gulf of Mexico and West Africa, stated, "The Gunflint project marks our fourth successful offshore major project completed within the past nine months, including the start-up of Big Bend and Dantzler in the Gulf of Mexico as well as the non-operated Alba B3 compression platform in Equatorial Guinea. Our drilling and completions teams delivered impressive technical accomplishments on the Gunflint development, including several innovative first time techniques for the industry. The coordination of simultaneous operations, including topside modifications at the floating production system and subsea well activities, is an accomplishment for all involved. The project was completed on time and under budget and will provide significant impact to Noble Energy as we progress through the rest of the year and into 2017."
Noble Energy operates the Gunflint field with a 31.14 percent working interest. Other working interest owners include Ecopetrol America Inc. with 31.50 percent, Samson Offshore Mapleleaf, LLC with 19.13 percent, and Marathon Oil Corporation with 18.23 percent.
Technip has been awarded a key contract by Repsol Sinopec Resources UK Limited for Inspection, Repair and Maintenance (IRM) works on its North Sea subsea infrastructure.
The frame agreement with Repsol Sinopec Resources UK will see Technip provide diving support and IRM services for 2016, with possible extension to include 2017 and 2018.
The frame agreement covers:
Technip’s operating centre in Aberdeen, United Kingdom, is managing the project.
The work scopes will utilize diving support vessels from the Group’s high performing fleet.
Bill Morrice, Managing Director of Technip’s UK operating centre, said: “I am delighted that Repsol Sinopec Resources UK has chosen Technip to support them in maintaining this important UK oil & gas infrastructure. We have an extensive track record in life of field extension work and have successfully delivered many projects of this type. Furthermore, in these difficult times for the industry, we are extremely pleased to be entrusted to deliver this work, and look forward to working with Repsol Sinopec Resources UK.”
North West safety seal manufacturer Roxtec has launched a new company called Roxtec Services AB targeting North Sea marine and offshore markets.
Roxtec Services AB was developed following sustained demand for equipment inspection on naval ships, drilling rigs and FPSOs (Floating Production Storage and Offloading anchored vessels). The initial focus for the new business will be in the North Sea and the UK continental shelf, an area where Britain has mineral rights – with a view of expanding into international territories including Asia and South America.
Roxtec UK managing director Graham O’Hare said the company will offer three main services to clients: inspection services, maintenance and training, which will all meet the highest worldwide standards.
“Roxtec's products are widely used in the oil and gas industry, so we’re very familiar with the needs of this sector, " he said. “Roxtec Services AB will deliver inspections, maintenance work and installation training within the crucial area of cable and pipe transits.
“The decision behind launching Roxtec Services AB stems from the demand we have witnessed to inspect some 50,000 multi-cable transits in the last 12 months.
“We will be looking to service marine vessels and offshore units. The reason it is so important is that firms must prove they are maintaining performance and meeting safety requirements from the classification societies governing the territory.
“Many classification societies already call for frequent transit inspections and we see a huge potential for the new company.
“The severe offshore environment causes severe material fatigue and means upgrades are frequently required to cables and pipes. Operators can suddenly find their rig or vessel is not protected against fire, gas and water according to the regulations.
“Roxtec’s experience as a global market leader in cable and pipe sealing solutions, with an international presence, means we are perfectly placed to advise and supply these types of projects which may ultimately involve multiple geographical locations.”
Roxtec Services AB will ensure that clients’ projects are fully compliant with international safety regulations pertaining to the use and maintenance of multi-cable transits.
It will see specialist offshore teams sent out to inspect assets on behalf of clients before reporting back with recommendations in line with relevant international safety standards.
Alternatively, it can also install an RFID (Radio-Frequency Identification) system to tag transits so they can be checked remotely.
Mr. O’Hare said: “Currently there are at least forty offshore assets under construction worldwide using Roxtec’s sealing solution, and it is pleasing that a number of these are taking place in the North Sea, which is the initial focus of Roxtec Services.
“Our mission is to provide clients complete assurance and peace of mind that their assets are operating efficiently and fully compliant with safety regulations. Our inspections will be able to assess if transits meet safety standards set by ABS, Lloyds, DNV GL and IMO.
“If the inspection report recommends corrective actions, the Roxtec Services maintenance team is ready to assist the operator with urgent actions onsite as well as with long-term services.
“A key part of the service is also educational. Our inspectors will look to share their knowledge by training installation teams and supervisors.”
API President and CEO Jack Gerard highlighted the benefits that come from increased oil and natural gas production after Democratic Presidential Nominee Hillary Clinton delivered her remarks at the party’s convention today.
“The production of energy resources holds great promise for our nation when it comes to creating jobs and benefitting consumers. It’s estimated that women and minorities will fill an exceptional number of the nearly 1.9 million jobs projected in the oil, natural gas, and petrochemical industries by 2035. And last year, American families saw higher household disposable income from increased energy production,” said Gerard. “Americans understand that pro-growth energy policies will create jobs and shrink the income inequality gap and it’s up to our nation’s leaders to follow the will of the American people.”
A recent poll found that 77 percent of voters, including 94 percent (R), 73 percent (I), and 64 percent (D), strongly support increased production of oil and natural gas resources located here in the U.S. and 69 percent of voters, including 86 percent (R), 69 percent (I), and 57 percent (D), are more likely to support candidates who want to produce more of our domestic oil and natural gas resources. The same poll found that 71 percent of voters, including 83 percent (R), 67 percent (I), and 60 percent (D), oppose legislation that could potentially raise energy costs on American consumers.
API is the only national trade association representing all facets of the oil and natural gas industry, which supports 9.8 million U.S. jobs and 8 percent of the U.S. economy. API’s more than 650 members include large integrated companies, as well as exploration and production, refining, marketing, pipeline, and marine businesses, and service and supply firms. They provide most of the nation’s energy and are backed by a growing grassroots movement of more than 30 million Americans.
Bureau of Ocean Energy Management (BOEM) Director Abigail Ross Hopper has announced that the bureau will offer 23.8 million acres offshore Texas for oil and gas exploration and development in a milestone lease sale that will include all available unleased areas in the Western Gulf of Mexico Planning Area.
“The Gulf of Mexico continues to be one of the most productive basins in the world and is an important part of our Nation’s domestic energy portfolio,” said Hopper. “This lease sale follows extensive environmental analysis and stakeholder engagement.”
Gulf of Mexico planning areas. Image courtesy: BOEM
The Western Gulf of Mexico Lease Sale 248, to be held on August 24, 2016, in New Orleans, Louisiana, will be the first federal offshore oil and gas auction broadcast live on the internet, delivering pertinent bid information immediately to a much broader national and international audience. Through this approach, BOEM aims to promote greater government efficiency and transparency, eliminating the need for the public to physically attend the bid reading at the Mercedes-Benz Superdome. The livestream broadcast will begin at 9 a.m. CDT via the BOEM website.
“Making government data immediately available is a valuable resource for taxpayers, both in terms of dollars and cents but also in efficiency,” said Hopper. “Through the use of technology we can deliver our lease sale information in a much more effective and accessible way to a much wider audience.”
Sale 248 will be the eleventh offshore sale in the Gulf of Mexico and the final sale for the Western Planning Area, under the Administration’s Outer Continental Shelf Oil and Gas Leasing Program for 2012-2017 (Five Year Program). This sale builds on the first ten sales in the current Five Year Program, which offered more than 60 million acres and netted nearly $3 billion for American taxpayers.
The auction will include approximately 4,399 blocks, located from nine to 250 nautical miles offshore, in water depths ranging from 16 to more than 10,975 feet (5 to 3,340 meters). As a result of offering this area for lease, BOEM estimates a range of economically recoverable hydrocarbons to be discovered and produced of 116 to 200 million barrels of oil and 538 to 938 billion cubic feet of natural gas.
Leases issued from this sale will also be the first for which BOEM will accept requests for extended initial periods, and confirm whether the lessee has earned such extension, a duty previously performed by the Bureau of Safety and Environmental Enforcement.
The decision to hold this sale follows extensive environmental analysis, public comment and consideration of the best scientific information available. The terms of the sale include stipulations to protect biologically sensitive resources, mitigate potential adverse effects on protected species and avoid potential conflicts associated with oil and gas development in the region.
All terms and conditions for Western Sale 248 are detailed in the Final Notice of Sale information package, which is available here. CDs and copies of the maps may be requested from the Gulf of Mexico Region’s Public Information Unit at 1201 Elmwood Park Boulevard, New Orleans, LA 70123, or at 800-200-GULF (4853).
The Notice of Availability of the Final Notice of Sale is available today for inspection in the Federal Register.
Sembcorp Marine, a global leader in offshore and marine engineering solutions, has delivered the world’s largest jack-up rig to Noble Corporation.
Noble Lloyd Noble, the seventh ultra high-specification harsh environment jack-up rig successfully completed for Noble Corporation, is based on the GustoMSC CJ70 design as well as Statoil’s ‘Category J’ specifications.
Image courtesy: Noble Corporation
The rig has an operational air gap of 69 meters and is capable of operating in a water depth of up to 150 metres (492 feet) in harsh environmental conditions. It boasts a maximum total drilling depth capacity of 10,000 meters (approximately 33,000 feet).
To be deployed in Statoil’s Mariner field development in the North Sea under a four-year charter arrangement, Noble Lloyd Noble is the first offshore structure of its kind to fully comply with both Norwegian and UK regulatory standards. It is uniquely suited for operation over a very large platform or in a subsea configuration.
The Noble Lloyd Noble project achieved 8 million man-hours worked without reportable incidents onboard the rig. It also scored a low Accident Frequency Rate (AFR) of 0.10 per million man-hours worked over a 31-month construction period.
Sembcorp Marine President and CEO Wong Weng Sun said: “The Noble Lloyd Noble reaffirms Sembcorp Marine’s ability to continuously scale new peaks as a manufacturer of the world’s most sophisticated rigs. With a global network of facilities, we are able to execute projects of any scale and complexity to high health, safety and environmental standards. We look forward to partnering with Noble Corporation again in building the best and most versatile offshore structures.”
Amec Foster Wheeler announces the award of two long-term major services contracts as part of Repsol Sinopec Resources UK's long-term transformation and long-term commitment to the North Sea. The contracts are both for an initial three-year term with up to two one year extensions.
The new contracts are for the provision of maintenance and construction labor and engineering support services, covering its offshore operated assets and the terminal at Flotta. In each category, contracts have been awarded to at least two providers to ensure best practice and to incentivise and reward performance and innovation.
The first contract is a new, simplified labor supply contract, replacing the previous maintenance services model. Amec Foster Wheeler's scope covers seven offshore assets: Arbroath; Bleo Holm; Buchan; Clyde; Claymore; Montrose; Tartan.
The second contract is for a tier 1 engineering services support, covering brownfield modifications and repair orders on a call-off basis, reflecting Repsol Sinopec's asset-based structure and allowing assets to align engineering scopes with suppliers whose core competence makes them best placed to execute them efficiently.
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