Thursday, June 30th, 2011
The International Association of Oil and Gas Producers (OGP) would like to announce the launch of the Seabed Survey Data Model (Version 1) at the ESRI Petroleum User Group conference. The data model has been in preparation since January 2010 with the support of support of oil and gas companies, survey companies and software vendors.
The aim of the data model is to:
• Facilitate a streamlined workflow for managing seabed survey data for oil and gas companies.
• Provide a consistent data model to enable simpler integration of seabed survey data.
• Enable the simpler exchange of seabed survey data with joint venture partners.
• Provide a industry data model that survey contractors can use for providing seabed survey deliverables.
What is the Seabed Survey Data Model?
The Seabed Survey Data Model is an industry template/standard for how seabed survey data is delivered to and then managed by oil and gas companies.
The main areas of SSDM application are:
• Platform and drilling hazard site surveys – shallow geophysical and high-resolution 2D/3D seismic.
• Sweep and bathymetric surveys – side scan sonar and singlebeam/multibeam echosounder.
• Pipeline route surveys, pipeline span/surveillance/inspection surveys using side scan sonar, but excluding ROV based pipeline inspection survey.
The Seabed Survey Data Model models the following data types collected and interpreted from seabed surveys: shallow
geohazards, seabed features, sediments, environmental samples, and bathymetry and survey project details.
What Does the Seabed Survey Data Model Comprise of?
• OGP Technical Guidance note.
• ESRI geodatabase template.
• Data dictionary.
• ESRI symbology stylesheet.
• Conceptual data model diagrams.
• FAQ’s document.
• User and contractor guideline.
• Corporate database (ArcSDE) implementation guide.
Where Can I Get Hold of the Seabed Survey Data Model Material?
The Seabed Survey Data Model forms part of a series of technical guidance notes and positioning data exchange formats that can be downloaded from http://info.ogp.org.uk/geodesy/.
Thursday, June 30th, 2011
The use of global navigation satellite systems (GNSS) for positioning is critical to the success of a wide variety of oil and gas-related surveying and positioning projects.
After an extensive review and update, the International Association of Oil & Gas Producers (OGP) and the International Marine Contractors Association (IMCA) have issued revised guidance for the use of GPS. OGP’s Geomatics Committee and IMCA’s Offshore Survey Division Management Committee were responsible for the work, based on a 1994 document produced by the UK Offshore Operators Association (now Oil & Gas UK). Representatives from the marine survey industry were also involved.
The new Guidelines for GNSS Positioning in the Oil and Gas Industry reflect the pervasive nature of the technology and the fact that GNSS is no longer specifically for the offshore industry. Though titled for use in GNSS surveying and positioning-related activities for the oil and gas industry, it could also be applicable to similar operations in the service of renewable energy, telecommunications and engineering projects both offshore and onshore.
The new Guidelines consist of seven sections. These include: an introduction summarising the global navigation satellite systems available and the observables; the relative and absolute positioning systems and techniques available; and updated coverage of the augmentation services that can be had from a variety of providers. Practical guidance is provided in sections dealing with installation and operation issues, geodetic considerations and atmospheric and other environmental influences.
Importantly, the new Guidelines retain recommended measures for assessing the quality of GNSS position fixes. The section on quality assessment and statistical testing includes examples and provides a comprehensive overview of the recommended statistical testing and quality measures based on the so-called Delft method.
Associated sections cover the recommended competence of operators and users as well as the various common data formats used for the exchange of positioning data.
Copies of Guidelines for GNSS Positioning in the Oil and Gas Industry can be downloaded free from www.ogp.org.uk or www.imca-int.com. Others, including training providers, libraries or other groups or individuals wishing to purchase printed copies can do so through the IMCA website.
Thursday, June 30th, 2011
A properly-conducted drilling hazard site survey for an offshore drilling location is essential. It minimises the risk of harm to personnel and equipment and helps to protect the natural environment.
The new Guidelines for the conduct of offshore drilling hazard site surveys describe oilfield good practice for conducting geophysical and hydrographic site surveys of proposed offshore drilling locations. The document also covers the use of exploration 3D seismic data to enhance, or to replace, acquisition of a site survey.
The Guidelines explain the requirements that different types of offshore drilling units have on a site survey. The new report also emphasises the differing site survey requirements of shelf and deep-water environments.
The new Guidelines summarise the objectives of site surveys, the site survey process, and provide suggestions on all the phases of a site survey. These include initial desk studies and planning, data requirements and geohazard analysis and reporting.
Associated technical notes, to be published separately later this year as OGP Report № 373-18-2, will provide supporting technical information and background theory on the various phases of a site survey project and on the vessels and equipment used to acquire site survey data.
The new Guidelines result from an extensive review and update of previously published work by UKOOA (now Oil & Gas UK). This review has been undertaken by a workgroup comprising representatives of OGP’s Geomatics Committee, as well as representatives from the marine survey industry and has resulted in a new, completely revised document.
The Guidelines are applicable for the conduct of offshore drilling hazard site surveys. While the document does not set out to directly address planning and delivery of other types of survey projects, the techniques described may also be applied to other types of seabed surveys, such as pipeline or cable route surveys, etc.
Copies of the Guidelines can be downloaded free from the ‘Publications’ section of www.ogp.org.uk as OGP Report № 373-18-1.
Thursday, June 30th, 2011
In terms of its market value, Petrobras, the Brazilian oil producer and refinery operator, is the eighth largest global company in the world. Its investments amount to more than $53 billion, and these include more than thirteen thousand productive oil and gas wells and 112 production platforms.
Recently the company implemented a corporate-wide protocol for evaluating the economic risks associated with potential investments. Key risks of interest to Petrobras include those associated with: the production of oil and natural gas; the demand for derivatives; the prices of various commodities; the start dates for various operations; and changes in company capital (CAPEX) and operating (OPEX) expenditures. In performing analysis of these risks, Petrobras looks to several key indicators: expected NPV; the standard deviation of NPV to get a sense of the risk associated with the reward; the probability of a negative NPV, or of losing money; and the 95% Value at Risk (VAR) of the NPV, which is the minimum amount that Petrobras stands a 5% chance of losing.
Petrobras’s Progride System
To evaluate these risks, the Exploration and Production (E & P) section of Petrobras developed an in-house system for corporate-wide use called Progride. Progride is based in Excel and uses customized C++ subroutines to perform it analyses. The company uses it to model a variety of E & P applications, including: oil trends like prices and spreads; income taxes and royalties; depreciation, residual value, and economic life of a project; sensitivity analysis; and other internal economic indicators. Progride also has risk analysis capabilities.
The system is capable of handling complexities such as multiple dependent projects (i.e. a base project plus complementary projects) within the same geographic site or “concession.” A concession represents the right for Petrobras to drill in a specific area, and typically carries with it obligations of rent, tax, and royalty payments. Proglide can also manage anticipated future production projects as well as projects that reduce operating expenses (i.e. have “negative” future operating expense).
Conventional Progride Analysis
E & P analysts at Petrobras enter a variety of data to run a conventional Progride analysis, making assumptions for what is uncertain. These data include: discount, inflation, tax and exchange rates; operation start dates; depreciation time; oil prices; production curves at the site for oil, natural gas, and water as well as water injection; capital expenditures such as drilling, surface installations, and collection; fixed and variable operating costs; and the cost of abandonment.
From such an analysis, Progride returns the NPV, IRR, and project return time; the best date for project abandonment; and the financial exposure to the company. However these results are based on best-guess point values in the input data that are assumed to be 100% certain. Thus risk is not taken into account.
Risk Analysis in Progride
For a risk analysis in Progride, analysts must construct distributions to represent ranges of possibilities for key input variables. These include: probabilistic production curves at the site for oil, natural gas, and water as well as water injection; unit production operational capacity; distributions for deviations in each CAPEX and OPEX component; and a distribution for the operation’s start date.
From this risk analysis, Progride provides the expected NPV of the project along with a histogram and measures of dispersion, or risk, around the expected NPV. It also estimates the probability of a negative NPV, or of losing money on the project.
Limitations of Progride
As useful as Progride is to Petrobras, it has a number of significant limitations that led the company to look to @RISK. For one, Progride’s risk analysis does not provide user access to the simulation data, preventing analysts from getting a closer look at different probabilistic scenarios. Furthermore, Progride cannot effectively handle more complex projects, such as those done in partnership with other companies, projects that share common infrastructure, or integrated projects with multiple concessions.
To illustrate the effect of these limitations, consider an integrated development project with production from two concessions, or specific sites. Petrobras invests in a single shared production oil flow unit to handle both concessions – a shared CAPEX. However, the company must treat each concession individually for Brazil’s National Petroleum Agency (ANP) for purposes such as area rent, royalties, and R&D.
In such a situation, risk analysis must be done on the integrated project as a whole. There are risk factors shared by both of the concessions, such as prices and CAPEX. And, there are independent risk factors, such as production and project start dates. However, some costs should be treated individually for each concession, like area rent, royalties, and R&D. Certain types of depreciation (on wells, for instance) should also be calculated for each concession as well. Multiple-concession projects are fairly common, yet Progride cannot analyze them without running for thousands of hours – an impractical, and potentially inaccurate, prospect.
The @RISK-Progride Solution
To address this problem, Petrobras E&P brought in @RISK. Rafael Hartke, who heads up financial planning and risk management for Petrobras’s investment operations, has developed a method to integrate @RISK with Progride, all in Excel. This system allows him to make an accurate and comprehensive assessment of a production platform with multiple concessions—and to save a huge amount of run time.
For the multiple concession project described above, the company sets up three separate Progride analyses – one for concession A, one for concession B, and one for the integrated project A+B. Then, analysts model probabilistic scenarios in @RISK for both the shared risk factors (prices, CAPEX deviations, e.g.) and the independent risks (production and start dates of operation, e.g.) for each concession. A conventional Progride analysis is performed for each concession individually, using the probabilistic scenarios generated by @RISK as input data. This analysis is performed while running @RISK by calling a macro that runs Progride during the @RISK simulation. The results of these two conventional concession analyses form the probabilistic scenario for each (e.g. production, revenue, CAPEX, OPEX, fiscal costs, and depreciation).
These individual concession results are then summed together to determine the probabilistic scenarios for the integrated project as a whole (A+B). Next, a conventional Progride analysis is performed on the integrated project in @RISK using the combined probabilistic scenarios as entry data. Desired risk indicators for the entire project are then calculated from the analysis results.
Easy as 3-2-1
The @RISK-Progride process can be summed up in 3 stages, 2 functions, and 1 macro.
The 3 stages of the process are:
Use @RISK to model and generate probabilistic scenarios for the shared and independent risk factors.
Link the probabilistic scenarios generated in @RISK to the input data of each concession’s conventional Progride analysis using the Excel’s Offset and @RISK’s RiskCurrentIter functions.
Execute each Prograde conventional analysis individually in @RISK, calling the macro which executes the Progride conventional analysis after each @RISK iteration.
The two primary functions used to accomplish the integration between @RISK and Progride are:
RiskCurrentIter(): This is an @RISK Statistics function which returns the value of the current iteration of the simulation while running.
Offset(cell ref, rows, columns): This is an Excel function which returns the value of a cell located a specified number of rows and columns from a particular cell reference.
Finally, there is only one macro needed in the process. @RISK is set to run this Excel macro after each iteration recalculation during a simulation. The macro simply runs Progride and contains the code: SendKeys “%PX”, True
Benefits of the @RISK-Progride Solution
Petrobras’s integrated solution gives the company a number of valuable benefits. First, it permits the separation of probabilistic scenarios for shared risk factors common to the projects being analyzed. Second, the use of @RISK allows the analysis of projects undertaken with partners. Similar to the above example, a separate Progride analysis is done for each partner, treating the fiscal aspects individually, but sharing the project risk factors. Third, as we’ve just seen, this approach enables the analysis of integrated projects with multiple concessions, with a separate Progride analysis for each concession that treats the fiscal and depreciation aspects individually while sharing project risk factors. Similarly, projects that share infrastructure with other, separate projects or concessions can now also be modeled in the same manner. Lastly, @RISK helps Petrobras reduce the calculation time for projections that used to take thousands of hours to a single day. If you multiply the saved hours by staff pay rates, you can get a pretty good picture of some huge cost savings.
» Integration of Corporate Systems and Risk Analysis
with @RISK,” Rafael Hartke, Petrobras. Delivered at the
Palisade Conference in Brazil, November 2009
Click here to read more from Craig Ferri, Palisades MD, on ROGTECmagazine.com
Thursday, June 30th, 2011
The X-Treme Clean XP system reduces operational risks in high-cost environments
Baker Hughes has introduced a wellbore clean-up and displacement system designed to improve efficiency and reduce operational risks in high-cost environments such as deepwater applications; horizontal, extended-reach, and deviated wells; deep wells; and wells with high dogleg severity. The X-Treme Clean™ XP system is the latest generation cyclone-based system, which removes debris more efficiently as a result of the industry’s highest allowable mandrel rotation speed, a non-rotating tool string, a large circulation area, advanced debris carrying capabilities, and higher-than-drillpipe tensile and torque ratings.
The X-Treme Clean XP system mandrel has an allowable rotation speed rated to 150 rpm versus 60-100 rpm for typical cleaning systems, and is designed to achieve the highest cleaning efficiency for every application. Studies indicate that cleaning efficiency increases significantly at 90-120 rpm. Only the mandrel rotates; other system components such as scraper blades, the brush, and stabilizers do not rotate, which is critical to minimizing damage to the casing, liner, or riser.
Additional features of the X-Treme Clean XP system include:
• The helical-shaped scraper and brush tools double the cleaning area and increase the annular circulation area, allowing fluid to circulate at high rates to reduce circulation and displacement time
• The downhole magnet strength surpasses the industry’s standard metal debris collecting capabilities
• The one-piece mandrel design allows higher-than-drillpipe tensile and torque rating, which dramatically mitigates operational risks
“The X-Treme Clean XP system offers a higher level of performance for the challenges our customers face in the most demanding applications,” says Neil Harrop, president, Completions and Production, Baker Hughes. “The system is designed to mitigate the risks inherent to these costly environments.”
Wednesday, June 29th, 2011
Acquisition marks a step change in development by fully combining Framo Engineering multiphase pumps and meter systems with Schlumberger subsea flow assurance and surveillance technologies.
Schlumberger (NYSE:SLB) announced today the acquisition of the remaining equity shares from Frank Mohn AS in Framo Engineering AS—a privately owned Norwegian company specialized in the business of developing, manufacturing and selling products and services relating to multiphase pumps and subsea pump-systems, multiphase metering systems, and swivels and marine systems to the oil and gas industry. The closing of the transaction is subject to regulatory approval.
Framo Engineering, founded in 1983, employs approximately 500 people, mostly in Norway. The company is the leading multiphase subsea pump and meter supplier, and has focused its investments in the development of new technology for oil and gas production from subsea wells—particularly in the emerging deepwater market. Subsea multiphase boosting can enable both ultra deepwater light-oil and heavy-oil production by increasing ultimate recovery of deepwater oil and gas fields.
“This transaction is an important step in the development of subsea technologies and solutions to improve hydrocarbon recovery and lower costs in the subsea environment,” commented Paal Kibsgaard, Chief Operating Officer, Schlumberger Limited. “The combination of Schlumberger subsea flow assurance and surveillance capabilities with Framo Engineering’s extensive subsea multiphase boosting and metering capabilities will help our customers better design their subsea infrastructure, optimize production and increase recovery over the life of the field.”
“I believe this to be a great opportunity for Framo Engineering and for all of its employees,” commented Ole Steine, Managing Director of Framo Engineering. “We are very pleased to be a Schlumberger company and see a fantastic future together by combining our skills. Our successful 14-year collaboration with Schlumberger for the development of the multiphase metering activity proved a good cultural fit between us that we believe will foster increasing innovation and create further opportunities.”
Frederik Mohn, Managing Director of Frank Mohn, minority owner, concluded: “We are proud to have been at the inception of Framo Engineering. The company has gone through an exciting transformation, considerably strengthening its strategic positioning and the depth of its management team. The sale to Schlumberger is an outstanding recognition of the value that has been created over many years. We are confident that being part of Schlumberger will enable Framo Engineering to take on the upcoming large integrated subsea projects worldwide, while clearly recognizing Norwegian skills.”
Wednesday, June 29th, 2011
International co-operation is essential if the challenge faced by the global oil and gas industry of successfully and responsibly exploring and developing the hydrocarbon resources that lie in the Arctic and sub-Arctic regions is to be met.
According to the two co-chairmen of the SPE Arctic & Extreme Environments (AEE) technical conference and exhibition taking place in October this year, competition would make everybody lose, while co-operation is likely to allow everyone to win.
Co-chair Anatoly Zolotukhin, Vice-Principal at Gubkin State University, commented: “In our opinion, the goal of this event is to raise general awareness of the challenges. To make everybody understand that developing the Arctic region is not an easy task, and not a task for a single operator, or even a single country. This is a global challenge of developing a whole region. Solutions may only be found in co-operation between the countries, not necessarily just the Arctic and sub-Arctic ones. Our goal is to bring forth the problems related to the Arctic and extreme environment plays, the complexity of these problems, and not only from the technological and engineering perspective but from the social, environmental and operating safety perspective too.”
Co-chair Sergey Brezitsky, VP Exploration & Production at TNK-BP, stressed the importance of learning from those with direct experience: “This is one of the major regions with undeveloped petroleum resources. Some companies and delegates have relevant experience. This is why it will be very useful to listen to peers such as BP, Shell and others, who possess real and valuable experience, having begun the development of such plays tens of years ago.”
Mr Brezitsky flagged up developments such as Prudhoe Bay in Alaska’s North Slope as an example of where such experience, ideas and solutions can come from. “There is no way to approach this region without advancing engineering solutions. This will ignite the advancement of associated industries related to petroleum and energy resources exploration and production in Russia,” he commented.
AEE chairmen discuss key topics in exclusive online TV interviews Both co-chairmen have given exclusive online on-camera interviews about the key topics to be discussed at SPE AEE 2011. For views and commentary from these two leading Russian oil industry figures go to www.arcticoilgas.com. Further subjects discussed include details of the planned plenary sessions and their topics; specific engineering and environmental challenges related to onshore and offshore operations in the Arctic region; lessons learned from current onshore projects; engineering solutions vital for future successful exploration and development in the Arctic and sub-arctic; the importance of demonstrating the industry’s ability to develop arctic and extreme environment plays in a safe and responsible way; the long-term vision for successful development of the Arctic regions.
The SPE AEE 2011 event from 18-20th October in Moscow, Russia will be the focal point of the industry’s efforts to tackle Arctic and extreme environments in a safe, efficient and environmentally sound manner, and with the key involvement of local people as stakeholders. Being held under the overall theme ‘Extreme Challenges for Exploration & Production’, the Call for Papers earlier this year has produced an outstanding technical program of papers and presentations from operator and service companies around the world, as well as research institutions and universities.
Plenary sessions over the course of the three-day event will focus on the following subjects: ‘Technology enablers to meet challenges of E&P’, ‘Future of Arctic Exploration’, and ‘Environment, Safety and Social Responsibility’.
The technical conference program, meanwhile, will cover categories including Exploration & Geology; Drilling & Well Construction Technology; Offshore & Onshore Technology; Production & Reservoir Management; Current Challenges of Arctic & Onshore Projects; Latest Technology & Technical Limits; Physical Environment & Human Capabilities for Arctic Field Development; and Arctic Pipelines.
In addition there will also be two Topical Breakfasts: one given by speakers from Schlumberger will focus on making reliability a ‘given’ in extreme environment operations; the other by Chevron Canada will discuss floating exploration drilling in the Beaufort Sea ‘Then and Now’. A Topical Luncheon on Day 1, meanwhile, will feature the Arctic Oil Spill Joint Industry Project, and will be given by SINTEF, while Day 2’s luncheon will be under the topic of ‘Addressing Arctic Aspiration’ and be given by Santec Consulting Ltd.
Companies currently confirmed to participate at SPE AEE 2011 include BP, Chevron, Gazprom, Lukoil, Rosneft, Statoil, Total, TNK-BP, Shell, Baker Hughes, Schlumberger, Bashneft, TMK and Polarcus, and many more.
The event at the All-Russia Exhibition Centre in Moscow will showcase the latest technology, products and solutions available to help the industry develop projects in arctic and extreme environments.
Official estimates put the amount of oil resources contained in Russia’s arctic shelf alone at 100 billion tonnes. Russia, Canada, Norway, the United States and Denmark are just some of the countries focused on the eventual and further development of their Arctic territories, both on and offshore, an area conservatively estimated by the U.S. Geological Survey organisation to hold up to 90 billion barrels of oil and 30% of the world’s undiscovered gas resources.
For more information go to: www.arcticoilgas.com. You can also find our group ‘Arctic & Extreme Environments Oil & Gas’ on www.LinkedIn.com, and can follow us via www.Twitter.com @SPE_Arctic.
Wednesday, June 29th, 2011
Exillon Energy plc, a UK-listed FTSE 250 independent oil producer with assets in two oil-rich regions of northern Russia, Timan-Pechora (“Exillon TP”) and West Siberia (“Exillon WS”), is pleased to announce preliminary results from Exploration Well 4 (EWS-10274).
Exploration Well 4 was designed to test an area between the EWS I and EWS II fields. Preliminary results of wire line logging confirmed the presence of 6.7 meters of effective net oil pay in an area that has not been previously studied. These results have expanded the management’s understanding of the outline of the EWS fields in a manner which may support further reserve growth.
The well encountered the Jurassic reservoir at 1,883 meters, and is currently being drilled deeper to assess the potential for further oil pay within the Pre Jurassic. Testing of the well is expected to be completed by the end of Q1 2012.
Tuesday, June 28th, 2011
Funds advanced science and technology education for women from developing nations
The Schlumberger Foundation announced today that it has received a $50 million grant from Schlumberger Limited and its subsidiaries to support the Faculty for the Future program. This flagship program, now in its sixth year, supports talented women scientists from the developing world by helping them pursue advanced graduate studies in scientific disciplines at leading universities worldwide.
In 2011, the Schlumberger Foundation awarded Faculty for the Future fellowships to 53 women from 31 countries to continue PhD or post-doctoral studies in 18 disciplines including civil and environmental science, computer engineering, chemistry, physics, mathematics, and hydrology. In addition, 45 existing grants were extended for a further period. Successful applicants are selected for their leadership qualities and scientific ability with the program attracting a total of 631 applications in 2011, including 48 requests for fellowship extension.
“The Schlumberger Foundation launched the Faculty for the Future program based on a conviction that the lack of female role models was one of the greatest roadblocks in preventing young women in developing nations and emerging countries from pursuing a scientific career,” commented Jean-Marc Perraud, Chairman and President, Schlumberger Foundation.
After completion of their studies, Faculty for the Future fellows return to their home countries to contribute to economic, social and technological advancement through strengthening the faculties of their home institutions and serving as powerful role models for other young women.
Schlumberger Foundation Receives $50 Million Donation for Flagship Faculty for the Future Program, pg. 2
Since its launch in 2004, 194 women from 54 countries have received Faculty for the Future fellowships for advanced graduate study at top universities around the world, and have become members of the active community of fellows. The new donation significantly reinforces the Foundation’s ability to fulfill the growth potential of the program.
For more information, visit www.facultyforthefuture.net/
About the Schlumberger Foundation – The Schlumberger Foundation is a private, nonprofit entity that supports science and technology education. Recognizing the link between science, technology and socio-economic development, as well as the key role of education in realizing individual potential, the Foundation’s flagship Faculty for the Future program succeeds a series of other educational initiatives.