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Technology Focus During the past years, several discoveries have been made in deep and ultradeep waters around the world. Many development projects are ongoing, and exploratory campaigns are increasing in this type of play. This latter factor will certainly result in new discoveries; it has already been seen in the presalt in Brazil, the Lower Tertiary in the deep water of the Gulf of Mexico, and the fields off the coast of West Africa. One of the challenges faced by the operators is making the appropriate selection for a field development plan. This is certainly the key to a successful project, requiring several studies by the operators to allow the technical groups to understand the complexity of the reservoir. The drilling costs in deep water continue to increase every day and represent the bigger portion of the capital expenditures for deepwater-field development. Therefore, having a good knowledge of the reservoir will help define the well design and architecture, optimizing the costs and maximizing the oil recovery. The papers selected for this month’s issue are related to deep- and ultradeep-water field development projects and are good examples of how operators are working on studies to help make the correct decision for the development plan to be selected. Please enjoy your reading. Recommended additional reading at OnePetro: www.onepetro.org. OTC 22993 The Who Dat Development: Evolution of a Project From Lease Sale to First Production by Rick Fowler, LLOG Exploration, et al. OTC 23172 Pazflor, a Major Step for Angola by Gaspar Martins, Sonangol OTC 22997 Overcoming Field Development Challenges in Depleting Ultra-HP/HT West Franklin Field by Slobodan Jezdimirovic, Total E&P, et al. SPE 147956 Modeling of a New Field Development Plan for a Giant Offshore Oil Field in the UAE by S. Bachar, Zakum Oil Development, et al.
- North America > United States (1.00)
- Africa (1.00)
- Europe > United Kingdom > North Sea > Central North Sea (0.59)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Block 29/05 > West Franklin Field (0.99)
- Africa > West Africa (0.89)
Green completions In its proposed New Source Performance Standards (NSPS) established in August 2011, the EPA estimated that, of the 25,000 new and modified fractured gas wells completed each year, approximately 3,000 to 4,000 currently employ reduced-emission completion (REC). Once finalized, the new rule will increase this number to more than 21,000 RECs annually as operators comply with the proposed NSPS. By 2015, every hydraulically fractured well will be required to use a green completion to capture and measure all oil and gas released during the flowback and drillout phases. Typically, the gas/liquid separator installed for normal well flow is not designed for the high-rate, four-phase (gas, hydrocarbon liquid, water, and sand) flow of a typical shale well. A common practice for the initial well completion has been to produce the well to a pit or tanks where water, hydrocarbon liquids, and sand are captured and slugs of gas vented to the atmosphere or flared. Completions can take anywhere from one day to several weeks, during which time a substantial amount of gas may be released to the atmosphere or flared. Green completion equipment is only necessary for the time it takes to complete the well. Operators typically transport this system from site to site to be used in a number of well completions, often on a truck-mounted skid. Don Atencio, manager at Fracmaster, said, “The setup for a green completion depends on the area and the type of well you are completing.” There is no set amount of equipment that is required. An REC can be performed with one self-contained unit, or it can be set up using individual components. Each job is based on need, the volume of gas and fluids being produced, and the size of the pad. For a multiwell pad, the equipment set up can be extensive. “Some of the work we are doing in New Mexico involves three major pieces of equipment that are too big to load onto one skid,” Atencio said.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.51)
- North America > United States > Wyoming > DJ (Denver-Julesburg) Basin > Niobrara Formation (0.99)
- North America > United States > Nebraska > DJ (Denver-Julesburg) Basin > Niobrara Formation (0.99)
- North America > United States > Kansas > DJ (Denver-Julesburg) Basin > Niobrara Formation (0.99)
- North America > United States > Colorado > DJ (Denver-Julesburg) Basin > Niobrara Formation (0.99)
An Occidental rig working in the Permian Basin of west Texas and New Mexico, an area of high activity for the company in mature field operations. Revitalizing these fields extends their The term mature field does not have a single definition. Individual A 2011 report, "Mature Oil Fields--Unleashing the companies may apply their own definitions. Potential," by IHS Cambridge Energy Research Associates, "We consider the subsurface and the surface," indicated that approximately two-thirds of global daily said Olivier Heugas, a member of the mature field team at average oil production comes from mature fields and that the Total's headquarters near Paris. "For the subsurface, we percentage is increasing over time. Regardless of the definition, mature fields are a huge global resource. With reserves categorized as proved or probable, attempts to expand reserve levels come at a relatively low risk. Modest additions to a base of this size can be very substantial. Revitalizing a mature field means taking measures that increase the value extracted from the field beyond original expectation. Every field has a production curve over which production grows to a peak level and then declines until it reaches the point at which operation is no longer economic. Revitalization extends the natural decline curve to increase ultimate economic hydrocarbon production. A variety of measures may be used, including the application of additional technology to characterize, monitor, and manage the producing reservoir; improve drilling and completions; and boost the recovery factor. Achieving significant cost reduction in field operations, through technology application or more effective work processes and business practices, can also play an important role. Although the aim of revitalization is to boost future production and recovery levels, it is crucial that an operator has first taken the steps to assure that original producible reserves goals are being met. Heugas explained Total's approach to revitalizing mature fields. "First, we must secure what we plan to produce from existing facilities, which are aging," he said. "And for that, we need to implement our development plans effectively for programs such as infill drilling and invest in maintenance.
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (61 more...)
Abstract This paper discusses how non-technical risks are impacting shale gas developments in Europe and how challenging it is to obtain the Social License to Operate. Although still at the early exploration phase, most European developments are already significantly hit by stakeholder concerns, lack of public acceptance and often lack of government support. Some European countries have even halted early exploration - at least temporarily - by political decision. Most of the public concerns are of environmental nature, especially linked to the use of chemical additives in the hydraulic fracturing process and related concerns about potential groundwater impacts, but hardly any is based on real events in Europe. Most concerns have developed on the back of perception and experiences in the US. This paper also takes a critical look at the discrepancy between public environmental concerns and real environmental risks. Initial experience in Europe has shown that the non-technical challenges have initially been underestimated, and that huge efforts are necessary to gain public acceptance and political support. A lot of efforts have already been put on stakeholder engagement, public information on technical processes, disclosure of chemicals and initial promotion campaigns, but the acceptance in most parts of Europe – Poland being the only exception - remains challenging. Besides technical and regulatory requirements, obtaining a "social license to operate" is thus of increasing importance for the success of a project.
- North America > United States (0.49)
- Europe > United Kingdom > England (0.30)
- Europe > France > Paris Basin (0.99)
- North America > United States > Ohio > Denmark Field (0.93)
- Europe > Sweden (0.93)
- (2 more...)
Abstract The drilling and completion of unconventional oil and gas wells requires more water than traditional wells, which makes water management critical. An emerging theme with unconventional resource development is the extent to which increased water needs for drilling and completion stress local water supplies. We will explore how drilling could potentially improve a community's access to water. In areas with limited water access, the benefits of necessary drilling infrastructure, like water wells, may extend beyond E&P operations to local communities and/or landowners. This paper highlights improved standards of living for local communities through access to fresh water. The case studies reviewed include improved water access for agriculture in California, beneficial produced water use in Australia, and shared water access near a drill site in Central America with neighborly behavior. The unintended importance of providing water and acting as good neighbors was that villagers chose to not engage with local guerrillas in a conflict to undermine drilling operations, and rather convinced the guerrillas to avoid the conflict altogether. The topics covered by this case study and others reveal the relationship between social responsibility issues; aspects of Safety, Security, Environment, and Health (SSEH); fresh water access and major resource utilizations in heavy security areas or developing countries.
- Oceania > Australia (1.00)
- Africa (1.00)
- North America > United States > Texas (0.68)
- North America > United States > California (0.48)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.69)
- Oceania > Australia > Queensland > Surat Basin (0.99)
- Oceania > Australia > Queensland > Central Highlands > Bowen Basin (0.99)
- Oceania > Australia > New South Wales > Surat Basin (0.99)
- (12 more...)
Abstract The paper will consider the implementation of the Safety Case in the oil and gas industry in Australia, and internationally, post the Macondo and Montara incidents. The National Commission Report into the Deepwater Horizon / Macondo blowout stated: In their letter to Minister Ferguson on 22 March 2011, the NOPSA Board stated: The paper will examine these criticisms and consider how the industry could improve its process safety and risk management. The implementation of a Safety Case in the USA may only occur "in the typical rule-making process that takes up to two years" (Michael Bromwich, Director of BOEMRE). Knowledge, understanding and application of key aspects of process safety management and the preparation and implementation of the Safety Case process are not uniform. The paper will suggest how, in this context, the Safety Case can be applied to achieve the improved outcomes. The paper will draw from specific findings from the Macondo and Montara incidents. In particular, and of some concern, there are echoes and parallels of the Piper Alpha disaster in the performance of emergency systems on Deepwater Horizon. Inadequate application of hazardous area classification is a key issue which the paper will discuss in order to provide greater understanding. Whilst in Australia, issues of competency, consistency and quality arise with matters such as performance standards. The paper will discuss the need for an industry accepted standard for "performance standards" that goes beyond current regulatory guidelines. Overall, the paper will seek to propose a way forward for the industry in several practical areas.
- Oceania > Australia (1.00)
- North America > United States (1.00)
- Government > Regional Government > North America Government > United States Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Mississippi Canyon > Block 252 > Macondo Field > Macondo 252 Well (0.93)
- Oceania > Australia > Western Australia > Timor Sea > Bonaparte Basin > Vulcan Basin > PL AC/L8 > Montara Field (0.91)
- Oceania > Australia > Western Australia > Timor Sea > Bonaparte Basin > Vulcan Basin > PL AC/L7 > Montara Field (0.91)
Abstract Technology is now available for real-time Industrial Hygiene monitoring of activities in locations such as offshore facilities, with viewing of the data remotely. The use of this technology can result in a more dynamic approach to hazard control, where the data being collected can be interpreted and control barriers altered in line with the results of monitoring. The data review can take place onshore by Industrial Hygiene specialists without the need to fly offshore. Encrypted data is transmitted via the internet for viewing onshore. No work on this application of real-time monitoring has been published previously. This innovative technology is being trailed by Shell in Australia in what is believed to be a world first. Real-time personal monitoring equipment is available for monitoring of compounds such as VOC (Volatile Organic Compounds), benzene, heat stress, radiation and dust. The application of this type of monitoring is extremely useful in a dynamic environment such as offshore exploration drilling or during commissioning of new offshore facilities. In these environments there is limited opportunity for specialist resources such as Industrial Hygienists to be present offshore as operationally, manning levels are at their maximum during these periods. The use of real-time monitoring with remote review by Industrial Hygiene specialist makes it possible to monitor unique, uncommon, or unplanned maintenance tasks that would otherwise be very difficult to capture. This paper will provide results and conclusions from the trial of this technology during the refit of an LNG Tanker in Singapore and will describe how this technology may be implemented in remote facilities such as Shell's Prelude FLNG facility. The paper will also discuss likely advances in this technology over the next few years.
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.89)
- Oceania > Australia > Western Australia > Western Australia > Timor Sea > Browse Basin (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Timor Sea > Browse Basin (0.99)
Abstract This paper examines the challenges associated with NORM disposal for the offshore oil and gas industry in Australia. This paper will address the Australian regulatory context and ‘textbook’ disposal alternatives and identify the approved avenues for disposal. Whilst this paper will reflect on how NORM is managed to minimise personnel and public exposure to NORM, in essence this paper will review regulatory considerations required for NORM disposal. This paper attempts to answer the question of, where to now with NORM disposal in Australia? The accumulation of Naturally Occurring Radioactive Material or "NORM" can occur during hydrocarbon production. During the extraction of hydrocarbons and associated formation fluids, some radioactive materials may become entrained and precipitate out of suspension in the form of sulfate and carbonate scale, sands and sludge. NORM has also been known to occur where there is a commingling of reservoir fluids and where there is a significant temperature or pressure decrease (i.e. as fluids flow from the production tree towards a production facility). For example, the injection of sea water has been known to assist in the formation of NORM as it can introduce sulphates to the reservoir which start to precipitate due to the reservoir containing soluble barium and trace concentrations of Ra-226 and Ra-228. NORM in the offshore petroleum industry is typically identified as Radium (usually Radium-226 and Radium-228) and Thorium (usually Thorium-228). These isotopes are purely radioactive and have no nuclear application. NORM activity levels have been observed to range from:
- North America > United States (0.89)
- North America > Canada (0.89)
Abstract While water-based fluids are generally preferred for drilling in environmentally sensitive locations, many are formulated with potassium chloride (KCl) to achieve good inhibition of reactive clays. The chloride ion however can be defined as a contaminant in land operations, with the potential to inhibit the growth of vegetation, and it can also be considered a potential pollutant to aquifers. In the rain forest region of the Southern Highlands of Papua New Guinea (PNG), an alternative to the KCl high performance water based fluid (HPWBF) was needed to mitigate environmental concerns, affirm the operator's commitment to sustainable operations and provide continuous improvement as required by ISO 14001. The fluid design team examined a range of alternatives and determined that potassium acetate (KAc) could replace KCl in the drilling fluid as a more environmentally acceptable inhibiting salt. Laboratory testing confirmed that the drilling performance properties of the fluid would not be impeded by substituting KAc for KCl. Experience using KAc fluids in other geographical areas was also examined to back up the laboratory testing. The original KCl-based HPWBF had historically helped reduce issues related to the longer step-out wells, directional complexity, rock tectonics, and wellbore stability in the area. The new KAc system was used equally successfully to drill seven challenging wells. Both the technical and environmental objectives of the wells were achieved without sacrificing drilling performance. The change to KAc increased the fluid cost by approximately 10% when compared to the KCl-based system, but the operator concluded that this was a good investment, considering the distinct environmental benefits. In a comprehensive review of the background to, and the successful implementation of the KAc HPWBF in to PNG Southern Highlands drilling, this paper firstly discusses the purposes of a drilling fluid. It will show how the presence of the potassium ion is regarded as essential within the drilling fluid, but the chloride ion has no discernible benefit. It considers the unique PNG Highland rainforest environment were the drilling operations occur, the local communities who live and interact with the operation, and how the operator has successfully protected this area. The drilling fluid disposal and discharge solutions in use in the Highlands operating area are discussed, how appropriate disposal solutions are selected, and how drilling fluid discharge is controlled to minimise any environmental impact. In the second half of the paper, the methods used to develop the new chlorides-free KAc HPWBF system will be discussed. Results will then be presented from the seven wells drilled with KAc HPWBF, with two previous KCl wells used as reference. It will demonstrate that along with the improved environmental acceptance, drilling fluid robustness was maintained, as was on bottom drilling performance. Finally a review of material usage and costs indicates the change to the new KAc fluid did not have as significant an impact as first assumed, as KAc concentrations within the HPWBF were optimized.
- Oceania > Papua New Guinea > Southern Highlands (0.28)
- North America > United States > Texas (0.28)
- Oceania > Papua New Guinea > Southern Highlands > Papuan Basin > PL 2 > Kutubu Field (0.99)
- Oceania > Papua New Guinea > Southern Highlands > Papuan Basin > PL 2 > Agogo Field (0.99)
- Oceania > Papua New Guinea > Southern Highlands > Papuan Basin > PDL 6 > Petroleum Development Licence-6 (PDL 6) > Moran Field (0.99)
- (11 more...)
- Well Drilling > Drilling Operations (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Health, Safety, Environment & Sustainability > Environment (1.00)
Abstract If the upstream petroleum industry wishes to retain its social licence to operate it should consider taking some additional steps to help prevent major accident events (MAEs). In Australia, establishing a Centre for Upstream Petroleum Safety (CUPS) based in Perth with an initial focus on human and organisational factors, safety culture and learning would be a concrete and substantive step forward to build capacity and capability. Internationally, an agreement among states and with industry is needed to require and protect reporting of more significant safety events, to systemically investigate MAEs and to promulgate lessons in a timely ‘no blame’ manner as occurs in aviation under Annex 13 to the Chicago Convention. Better learning from past MAEs in oil and gas and from other high risk and high technology industries such as transport, nuclear, underground coal mining and petrochemicals is also crucial. Some examples of such MAEs are provided and key aspects of the billion dollar Varanus Island gas pipeline explosions that occurred in Western Australia in June 2008 are highlighted. Incorporating these into an active learning CUPS curriculum would help build local capacity and capability to prevent future MAEs.
- Europe (1.00)
- Oceania > Australia > Western Australia (0.48)
- North America > United States > Illinois > Cook County > Chicago (0.24)
- Government > Regional Government > Oceania Government > Australia Government (1.00)
- Government > Regional Government > North America Government > United States Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Area do 1-RJS-366 > Frade Block > Frade Field (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Mississippi Canyon > Block 252 > Macondo Field > Macondo 252 Well (0.99)
- Health, Safety, Environment & Sustainability > Safety > Human factors (engineering and behavioral aspects) (1.00)
- Health, Safety, Environment & Sustainability > HSSE & Social Responsibility Management > HSSE management systems (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers (1.00)
- (4 more...)