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Add to Calendar 05/24/2022 09:00 AM 05/24/2022 09:30 AM America/Chicago Extending the Life of Maturing Assets with a Production Enhancement Model The SPE Tech Talk, "Extending the Life of Maturing Assets with a Production Enhancement Model" has been postponed. A new date is not available at this time. We are sorry for any inconvenience this may cause you. To see other upcoming SPE Lives and Tech Talks that are broadcasting soon, please visit the Energy Stream site.
Today more than 62% of the world's production comes from mature assets, and this percentage is expected to grow to 77% by 2030. Our industry is increasingly relying on interventions to meet this demand. However, almost 35% of interventions don't meet the objectives in terms of incremental barrels, primarily because of the reactive and siloed intervention approach used. SLB production enhancement projects leverage SLB's differentiated domain expertise, technology portfolio, and digital workflows to drive proactive intervention and stimulation solutions. This reduces the cost of the value chain, with a 30% lower cost per barrel and 33%lower carbon footprint per barrel as opposed to infill drilling. Join Paul Hultzsch and Dr. Ali Jama as they discuss how SLB production enhancement projects can help oil and gas operators increase their intervention success rate and maximize recovery from brownfields through advanced technical solutions and alignment of success criteria to achieve a win-win outcome.
Summary Traveltime or time fields contain informations on wave field properties of seismic waves. The wavefront curvature corresponds to one of the most important wave field properties. It is related to the normal moveout and the geometrical spreading and therefore leads to many important applications in seismic data processing, e.g., computation of migration weights, NMO corrections, Fresnel zones as well as an accurate and economical interpolation of traveltimes. We presenta technique, which is based on the assumption that any arbitrarily shaped wavefront can locally be approximated by a sphere. No particular type of model is assumed.
ABSTRACT: We all know that the most common artificial lift techniques in the oil industry are the Electrical Submersible Pump (ESP), Gas lift and Sucker rod pump. This paper will discuss the ESP's performance history in Khalda petroleum company and the experience that was gained through the past 16 years of utilizing this technique among 15 fields with capacities ranged from + 150 BFPD up to + 3,500 BFPD. Sixteen years ago, KPC conducted a comprehensive study to select the most appropriate artificial lift technique (technically & economically) to be applied in its fields which were discovered at that time (Salam, Safir & Khalda).By 1989 KPC had 27 wells which were equipped with ESP's in Salam, Safir, Khalda, Hayat & Tut fields. The ESP's lifetime of these fields didn't exceed 300 days. However, KPC's management & staff went through continuous efforts to reduce well interventions, increase pump and well uptime, improve pump operations and optimize the well production consequently reduce the cost-effective Installation and maintenance. These efforts were basically directed into two main objectives:–Improvement of manpower qualifications and skills. –Equipment selection & integration. For the manpower, an intensive training program was developed including classroom & on job training, abroad training, and the utilization of the training facilities that existed in some of the sister companies. For the equipment, during the first five years of the utilization of ESP's, Khalda's staff was able to establish comprehensive data base program that include but not limited to the reservoir & fluid characteristics, equipment specifications, well bore condition, equipment failure analysis program and equipment performance evaluation. Focusing on these two objectives has helped very much in improving the manpower technical skills & ESP head office & field team performance. Also identifying the reasons behind the failure of each ESP component and the remedial action. As a corrective action to overcome the bad effect of the free gas percentage into pump due to reservoir depletion, Khalda has studied the problem and used the new ESP technology device that has the capability to handle a huge amount of gas up to 40% free gas into the pump. Also, With increasing the percentage of the produced water it was observed increase in corrosion rate in the production tubing and the carbon steel ESP component, so a corrosion inhibitor program has been implemented using the Round cable with injection tube in addition using 9% chrome ESP equipment in the problematic wells. On the other hand data acquisition system using the down hole multi-sensor helps for closely follow up the ESP Performance through the down hole operating parameter such as Pump intake pressure, Motor temperature, Pump discharge pressure,... etc and take the corrective action(s) on time, subsequently prevent the premature failure. The results of all these efforts and others had a great impact on the ESP's lifetime of KPC fields, consequently a magnificent reduction in the cost/bbl related to ESP operations was achieved
- Africa > Middle East > Egypt (0.69)
- Asia (0.50)
Abstract In volatile times, when oil prices are in a decline, efficiencies and asset utilization are critical elements to ensure sustainability in the market for both operators and service companies. However, maximizing utilization and pushing equipment to the maximum could potentially have negative repercussions and ultimately result in failures causing loss of time and other potential damages. Thus is it critical to closely monitor and evaluate the assets conditions to ensure both safe and efficient operations are performed. In the case of coiled tubing (CT) strings, monitoring and proper evaluation can be performed by utilizing an infield nondestructive evaluation (NDE) device that employs magnetic flux leakage (MFL) to detect flaws and monitor, wall thickness, outer diameter, and various other properties. The real-time device requires no direct contact with pipe, and its compact design allows it to be run continuously throughout the life of the CT. Damage can then be detected and managed before a failure occurs. The ultimate goal is to reduce CT failures while increasing CT longevity throughout the operations. This paper covers three specific examples of NDE inspection conducted on site that increased the utilization of the CT string without compromising the service quality delivery. It also reviews the various parameters that were monitored and evaluated on location and the decision-making process used to keep the strings in service longer than previous methods would have allowed thus safely increasing the utilization and improving the efficiency. The first two cases are out of Texas, USA. The objective of the NDE was monitoring the pipe for corrosion or physical plastic deformation. This region regularly performs high-pressure cycling operations and in the past relied mostly on calculated fatigue models with significant derated values and safety factors to retire strings from use. Utilizing the scanning devices from after manufacturing through the strings' life allowed both the operator and the service company get more useable footage and still retire the strings after getting indications of irreversible geometric changes. They were able to plan and control the CT retirement around operational well plans to ensure no delays were seen in the field. The third example is out of Alberta, Canada. A CT string being used on a long-term project was damaged. The NDE inspection allowed for continued use of a pipe that had visible surface damage. In the past, this string would have been immediately retired and removed from service after a mechanical defect of the same nature was observed; however, the NDE device aided in adressing the severity of the damage, by MFL, and monitored its progress while continuing to use the string. The 2.375-in. string was able to be run an additional 53,203-m [174,550-ft] in a safe and controlled manner before reaching retirement.
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Sabinas - Rio Grande Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Maverick Basin > Eagle Ford Shale Formation (0.99)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Deep Basin > Cardium Field > Cardium Formation (0.94)