Real time tubing inspection during hoist interventions was implemented in South Oman in late 2007. It utilizes the principle of electromagnetic pipe inspection. The technique is similar to conventional yard based electro magnetic tubing inspection, the difference being that yard inspection is performed on the ground whereas real time tubing inspection is performed on the well. It provides scientific assessment of tubing condition in real time.
The environmental impact of oil spillage and additional costs associated in oil fields is an important matter, especially in large oil fields, where well sites monitoring and spills prevention are not easy tasks; therefore a new spillage management detection is an utmost required.Petroleum Development Oman (PDO) has more than 1700 Beam lift wells operating in the South Oil Directorate. In the latest years the Stuffing Box (SB) leaks have become a serious issue in field operations, causing a severe environmental impact as well as a significant additional operational costs and unscheduled production deferment.In most of the cases the SB leaks are related to wellhead or Beam Pumping surface unit misalignment, which somehow affect the mechanical condition of Polished Rod (PR) limiting its run life. When the PR is not aligned with the axial bore of the SB a lateral force exerts upon the SB by the PR is producing severe wear and premature failure of its rubbers elements resulting in SB leaks. In many cases when the SB leak begins, the spillage get overflow on the location resulting in an environment damage and unnecessary deferment due to BP outage.Solution to the above problem lies in automation, which is also key success factor in every phase of oil production process. It allows production processes monitoring, as well as its optimization and controlling, aiming to reduce costs and maximizing the overall system efficiency. The tangible and intangible savings generated by these automation systems have exceeded customer/operator's expectations in all cases, where spills have been significantly reduced and early SB leaks have been successfully detected and corrective action there upon taken.This paper gathers the results of field investigations conducted to understand causes behind of SB's integrity loss, which might lead to severe fluid spillage on well locations. Furthermore, presents the new operational philosophy, which could reduce company exposure in terms of HSE risks and additional operational costs associated with management of oil spillage.
In fields with large number of wells, any improvement in the monitoring and production optimization processes can have a significant impact in the overall field performance.With this vision, in April 2012, a new tool for optimizing PCP wells was introduced in Petroleum Developments Oman (PDO) as a trial. This new setup was based on enabling Pressure Control Setup (PCS) control that would allow the PCP speed to be adjusted based on well/reservoir potential assessed by a measurement from a downhole pressure gauge. The downhole pressure value is used as target value for this PCS controller. This paper describes the main benefits about implement a PCS loop after implementation in two pilot PCP wells based on intake pressure. This setup enhances well operation by timely maximizing production and/or accelerating production optimization, protecting the pump against running dry and protecting the reservoir should a lower pressure limit be reached, e.g. a limit that can onset sand production or water coning.An additional benefit of using this tool is the reduction of the required manpower which also reduces the HSE exposure due to less mobilization and traveling time, for the well optimization.
Streamline simulation is an ideal reservoir management tool for mature waterfloods since it can identify unswept reserves, quickly evaluate multiple forecast scenarios, and provides novel information like well-pair interactions. The identification of well-pair interactions is particularly useful as it allows for pattern surveillance, quantifying offset production with injection volumes, and identifying efficient vs inefficient areas of injection. The Thuleilat heavy-oil field consists of 120 wells and is geologically complex with stacked reservoirs, multiple oil-water contacts, and numerous faults, making it difficult to identify well interactions and areas of unswept reserves. However, being a dead oil reservoir with the majority of production a result of injection, it is ideally suited for streamline simulation. Several opportunities were identified based on the streamline simulation. These opportunities, which generally apply to all waterfloods, could be divided into well rate target recommendations, pattern optimization, producer-injector conversions, and infill locations. Pattern optimization opportunities resulted in a 10% gain in the offset oil producers. In one of the pattern optimization activities three water injectors were identified for injection rate increase, followed by optimization activities in the associated oil producers which resulted in a significant oil gain. Other pattern optimization activities were to close in high gross rate wells and diverting the flow toward offsets oil producers. One of the trials was to close-in one of the producers in the central area for one week, which resulted in a measurable oil gain in 3 offset oil producer wells. The second activity was closing another producer in the northern sector for two weeks which resulted in an oil gain in 5 offset oil producers. Further use of the streamline model includes the assessment of unswept reservoirs for infill locations and the estimation of water cuts for development locations. Introduction Numerous authors have already shown the possibility of building complex history match streamline models for waterfloods.1–7 Many of these authors have also used their streamline models in a manner similar to finite-difference (FD) models for waterflood management, such as forecasting, testing infill locations, and identifying bypassed oil. Recently Thiele & Batycky9 showed how to use the novel information of well-pair connections from streamline simulation to improve flood performance. Specifically, alter well rates to increase oil production and reduce fluid cycling. However, there is little if any documented results of altering well rates based on streamline identified well-pairs, and what the outcomes were. The purpose of this paper is to show the results of implementing well rate changes to the Thuleilat field, based on a streamline model, and what changes to production actually occurred. The Thuleilat field is located on the eastern side of the South Oman basin approximately 200 km NE of Salalah Figure 1. This is a heavy oil field that has a STOIIP of some 96 Mln m3, and has been on production since 1987. Details of the geology and production of the field are described below.
TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractStreamline simulation is an ideal reservoir management tool for mature waterfloods since it can identify unswept reserves, quickly evaluate multiple forecast scenarios, and provides novel information like well-pair interactions.The identification of well-pair interactions is particularly useful as it allows for pattern surveillance, quantifying offset production with injection volumes, and identifying efficient vs inefficient areas of injection.The Thuleilat heavy-oil field consists of 120 wells and is geologically complex with stacked reservoirs, multiple oilwater contacts, and numerous faults, making it difficult to identify well interactions and areas of unswept reserves. However, being a dead oil reservoir with the majority of production a result of injection, it is ideally suited for streamline simulation. Several opportunities were identified based on the streamline simulation. These opportunities, which generally apply to all waterfloods, could be divided into well rate target recommendations, pattern optimization, producer-injector conversions, and infill locations.Pattern optimization opportunities resulted in a 10% gain in the offset oil producers. In one of the pattern optimization activities three water injectors were identified for injection rate increase, followed by optimization activities in the associated oil producers which resulted in a significant oil gain. Other pattern optimization activities were to close in high gross rate wells and diverting the flow toward offsets oil producers. One of the trials was to close-in one of the producers in the central area for one week, which resulted in a measurable oil gain in 3 offset oil producer wells. The second activity was closing another producer in the northern sector for two weeks which resulted in an oil gain in 5 offset oil producers. Further use of the streamline model includes the assessment of unswept reservoirs for infill locations and the estimation of water cuts for development locations.
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