Objectives/Scope Generally, tight reservoirs require hydraulic fracturing to enhance and sustain hydrocarbon production. However, fracturing requires frac string with bigger Internal Diameter (ID) to minimize frictional losses during hydraulic fracturing operation. This string ID may not be suitable to provide optimum Vertical Lift Performance (VLP) during production phase, particularly in oil wells. Therefore, it is required to replace the frac string with production string of smaller ID. Occasionally, artificial lift also becomes essential to overcome VLP issues in future due to progressive water production and declining reservoir pressure. Methods, Procedures, Process Completion replacement often causes reservoir damage due to killing operation, which can be removed in conventional carbonate reservoirs by matrix stimulation. However, formation damage removal is difficult in hydraulically fractured tight carbonate and sandstone reservoirs. Preventive measures become essential to avoid productivity impairment particularly in hydraulically fractured reservoirs. Different preventative options are proposed and reviewed to isolate reservoir with their advantages and disadvantages. After comprehensive studies and risk assessments, an innovative modification in the completion plan was introduced and finalized. This plan includes production string with Electrical Submersible Pump (ESP) to improve VLP. This completion provides full accessibility intervention job, which may be required for reservoir monitoring and surveillance in future. Results, Observations, Conclusions A comprehensive production test is performed to evaluate and compare the testing results of pre and post workover. Testing results show there is no impairment in productivity of the reservoir, which is avoided in workover process by isolating reservoir section. This paper summarizes the completion design process, selection criteria, challenges, and lessons learnt during design and execution phases. This technique will provide the guidelines for installation of the Production string/ESP in hydraulically fractured reservoir without productivity impairment. Novel/Additive Information With modified design, the reservoir is isolated from wellbore and completion with ESP is run successfully without killing reservoir section. Underbalance conditions are achieved prior to establishing communication between reservoir and wellbore.
More than 155 Electrical Submersible Pumps (ESP) are installed in water supply wells in one of United Arab Emirates – Abu Dhabi Onshore area fields (ADCO). The water supply wells producing wells are characterized by low reservoir pressures, high production rates, low levels of H2S and toxic gas. The produced reservoir formations mainly consist of soft limestone and with variable porosity. This paper will highlight the major techniques used to boost ESP system run life and enhance reliability in onshore application. These techniques are as follow: Equipment selection - Redesigning equipment to adapt to reservoir parameters and productionUpgrading of ESP equipment, accessories, seals and consumables to withstand reservoir pressure and fluid propertiesOperation Practice Developing guidelines to enhance operation practice and test equipment integrity in workshopWell condition –Monitor the well condition and advice field production and operation team to schedule the well for periodic clean out and stimulation to enhance the production The above technical enhancements made were to improve ESP performance in scale forming and corrosive environments. The focus will be on case histories to discuss what was implemented and the methodologies that were used to overcome specific challenges encountered with the use of ESPs. The analyses will overview ESP failures from the period 2011 to 2016. These proposed solutions helped the in improving overall ESP system run life and reliability from 459 days (year of 2013) to 878 run days (year of 2016). It also helped the in reducing the MTBF (Mean to before failure) from 581 days (year of 2013) to 1079 run days (year of 2016). Additionally it reduced the OPEX by 35%, ESP failures in ESP water supply wells from 35 failures (2013) to 18 failures (2016), well down time, and potential HSE risk related to well intervention and work overs.(fig 01) Figure 1No. of ESP failures in water supply wells
This paper reviews the production optimization strategy of an artificial lift system that has been implemented in a carbonate reservoir in an Abu Dhabi onshore field. The adapted optimization technique assures the mitigation of the main challenges related to reservoir heterogeneities, in addition to completion design which has a significant impact on ESPs sizing, operation and optimization processes. An integration approach of reservoir dynamic data and ESP performance was established as a guideline for ESP surveillance, diagnostic and targeting candidate for production optimization by implementing at least one of the possible solutions: (a) upgrading ESP-surface equipment, (b) anticipate WO for re-sizing & ESP Deeping jobs, (c) well design strategy review. The result of this effort demonstrates the successful implementing of proposed solutions by enhancing the oil production by more than 20% in all separates pilot tests conducted in the field. The project success can lead the way forward for future ESP application in similar harsh down hole conditions.
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