Successful Development of Residual Gas Condensate Reservoir using First ESP in Deep High Pressure and Temperature in Rich Gas Condensate Wells

2021 ◽  
Author(s):  
Abdullah Salim Shuely ◽  
Hilal Sheibani ◽  
Hawraa Al Lawati ◽  
Patrick Ezechie ◽  
Roeland van Gilst ◽  
...  
Keyword(s):  
Technology Implementation ◽  
Success Factors ◽  
Gas Condensate ◽  
High Rate ◽  
Geological Time ◽  
Gas Field ◽  
Produce Water ◽  
Full Field ◽  
Well Completion ◽  
Residual Gas

Abstract A rich condensate gas field is located in the North of Oman, which penetrated the Amin sandstone reservoir at 4015 TVDmss. A study was conducted in the field and showed there is ¾ of GIIP trapped with paleo imbibition - over geological time - gas by the water encroachment in an approximately 80 m thick Paleo-Residual Gas zone (PRG), with very low mobility of hydrocarbons and high residual gas saturations. In order to mitigate the shortcomings of such unfavorable subsurface conditions, the study proposed Gas-Aquifer-Rate Management (i.e. co-production of gas and water) utilizing existing flank wells, as a potential field improvement option. The key business drivers for this project are to re-mobilize gas from PRG flank wells and to safeguard existing NFA by Aquifer pump off and production from high rate crestal wells. The optimum gas well deliquification method has been identified based on the highest UR considering connected GIIP and well completion size. The outcome of the study indicated that the ESP technology combined with well retubing was recommended as the optimum solution. Two wells have been selected as ESP candidates to test the new technology to produce water at deep depth (4000m) and high temperature (155°C). A special slim ESP was designed for this purpose. A successful pilot was completed in one well and gave conclusive results. The test showed that the well produced 3K m3/d of gas and 83 m3/d of liquid with 95% BSW. The second pilot is currently in the commissioning phase. The successful outcomes of the pilot succeeding in connecting the gas and restoring wells back with economic production rates will lead to expedite a full field implementation plan. This project will add a significant economic value of positive NPV at low UTC. This paper will highlight the full story of the PRG and ESP technology implementation and describe in details the entire process starting from the artificial lift selection, well candidate selection screening criteria, critical success factors, operating parameters, life-time cycle and the test results of gas and condensate and water production. Also, the learning and challenges in operating the ESP will be shared.

A Comprehensive Study Developing and Maximizing the Recovery of Gas Condensate from a Giant Onshore Abu Dhabi Gas Field Utilizing Advanced Condensate Tracking, Gas Injection and Drilling Strategies in Next-generation Commercial Numerical Simulator

2021 ◽  
Author(s):  
Bondan Bernadi ◽  
Ihab Nabil Mohamed ◽  
Ahmed Mohamed Al Bairaq ◽  
Mariam Ahmed Al Hosani ◽  
Azer Abdullayev ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Gas Condensate ◽  
Drop Out ◽  
Abu Dhabi ◽  
Next Generation ◽  
Gas Field ◽  
Full Field ◽  
Oil Rim ◽  
Numerical Simulator ◽  
Comprehensive Study

Abstract A comprehensive study of a giant onshore Abu Dhabi gas field using a next-generation commercial numerical simulator has been conducted. The objective was to identify the distribution and track the movement of the gas condensate in the reservoir, and to develop strategies to minimize the condensate drop-out and improve condensate recovery from the field. The field contains a large gas cap and an oil rim. We have identified the distribution of the gas condensate throughout the reservoir and were able to track its movement using the advanced fluid tracking option in the simulator. Once the gas condensate drop-out regions in the reservoir are identified, sensitivity runs with localized changes are carried out to improve the recovery from the reservoir. The strategies to mitigate drop-out include adding infill wells, drilling multi-lateral wells, reinjecting CO2 and dry gas into the reservoir, and hydraulic fracturing near the well bore. We were able to track the distribution of the condensate throughout the reservoir and identified key condensate drop-out regions. Adding infill wells improved the recovery of the condensate. Implementing multi-lateral wells also showed improved condensate recovery in the field. Hydraulic fracturing near the wellbore reduced condensate banking near the wellbore. Injecting dry gas improved the condensate recovery by a re-vaporization process where the liquid condensate is absorbed by dry gas. This paper discusses a comprehensive study on tracking the condensate distribution in a giant onshore field using a commercial simulator. The authors have performed a thorough investigation to identify an optimal condensate recovery strategy for the field, by comparing various recovery strategies using the full field reservoir simulation model.

Study on the Characteristics of Well Completion Technology in Deepwater Oil and Gas Field Development

2021 ◽  
Vol 3 (8) ◽  
pp. 70-72
Author(s):  
Jianbo Hu ◽  
◽  
Yifeng Di ◽  
Qisheng Tang ◽  
Ren Wen ◽  
...  
Keyword(s):  
Deep Water ◽  
Deep Sea ◽  
Oil And Gas ◽  
Gas Field ◽  
Marine Research ◽  
Field Development ◽  
Research Technology ◽  
Well Completion ◽  
Development Capacity ◽  
Exploration And Development

In recent years, China has made certain achievements in shallow sea petroleum geological exploration and development, but the exploration of deep water areas is still in the initial stage, and the water depth in the South China Sea is generally 500 to 2000 meters, which is a deep water operation area. Although China has made some progress in the field of deep-water development of petroleum technology research, but compared with the international advanced countries in marine science and technology, there is a large gap, in the international competition is at a disadvantage, marine research technology and equipment is relatively backward, deep-sea resources exploration and development capacity is insufficient, high-end technology to foreign dependence. In order to better develop China's deep-sea oil and gas resources, it is necessary to strengthen the development of drilling and completion technology in the oil industry drilling engineering. This paper briefly describes the research overview, technical difficulties, design principles and main contents of the completion technology in deepwater drilling and completion engineering. It is expected to have some significance for the development of deepwater oil and gas fields in China.

Minimization of Negative Impact of Well Cementing on Productive Horizons by Utilization of Swellable Packers

2021 ◽  
Author(s):  
Mykhaylo Paduchak ◽  
Viktor Dudzych ◽  
Anatolii Boiko
Keyword(s):  
Negative Impact ◽  
Differential Pressure ◽  
High Rate ◽  
Donets Basin ◽  
Technical Solution ◽  
Negative Consequences ◽  
Well Completion ◽  
Stable Production ◽  
Geological Conditions ◽  
Gas Tight

Abstract Avoiding of negative impact of slurry contact with productive sections by utilization of swellable pakers well completion systems as a key solution for depleted reservoirs. Results are compared to previously used classic well completion method with production casing cementing The new method of the well completion is based on a long period and many wells operations within Svyrydivske field in Dnipro-Donets Basin (here and after DDB). Precise selection of hybrid, oil and water based elastomers and correct placement in the appropriate hole zones for water and sectional isolation together with oil based mud utilization during drilling have provided stable production in depleted reservoirs and have minimized negative consequences from water filtration. The results achieved and the well completion method are described in detail to allow readers to replicate all results in a comparable geological conditions in DDB. Current well completion method has a couple of outstanding results achieved: –well integrity barrier is based on sufficient differential pressure provided by swellable packers;–reliable long term water isolation of all detected water contained intervals;–the production sections are not polluted by slurry filtrated water;–increased production rate comparing to cemented wells;–no risks of slurry loss during well cementing. This technology has been successfully implemented in both vertical and deviated wells on 4.5″ (114.3 mm) casing OD, in the interval 5100-5450 meters, bottom hole temperature 120-135°C. The differential pressure provided by swellable packer is up to 10,000 PSI (68.9 MPa). Fluid reactive packers are ready to expand and isolate highly cavernous hole sections and keep differential pressure sustainably. To achieve the best results with this well completion method, it is also important to use reliable gas tight casing connections and know precise reservoir characteristics. That is why the technology is recommended to be customized for well known brownfield reservoirs with high rate of depletion. The main benefit of the well completion method is a proved and safe technical solution for mainly depleted deep gas and condensate deposits in DDB (Ukraine) with sensitive economics

scholarly journals The Waitsia Field, onshore North Perth Basin, Western Australia

2016 ◽  
Vol 56 (1) ◽  
pp. 29 ◽  
Author(s):  
Neil Tupper ◽  
Eric Matthews ◽  
Gareth Cooper ◽  
Andy Furniss ◽  
Tim Hicks ◽  
...  
Keyword(s):  
Flow Characteristics ◽  
Development Planning ◽  
Upper Permian ◽  
Depth Interval ◽  
Lower Permian ◽  
Minimal Processing ◽  
Gas Field ◽  
Full Field ◽  
Field Development ◽  
Primary Porosity

The Waitsia Field represents a new commercial play for the onshore north Perth Basin with potential to deliver substantial reserves and production to the domestic gas market. The discovery was made in 2014 by deepening of the Senecio–3 appraisal well to evaluate secondary reservoir targets. The well successfully delineated the extent of the primary target in the Upper Permian Dongara and Wagina sandstones of the Senecio gas field but also encountered a combination of good-quality and tight gas pay in the underlying Lower Permian Kingia and High Cliff sandstones. The drilling of the Waitsia–1 and Waitsia–2 wells in 2015, and testing of Senecio-3 and Waitsia-1, confirmed the discovery of a large gas field with excellent flow characteristics. Wireline log and pressure data define a gross gas column in excess of 350 m trapped within a low-side fault closure that extends across 50 km2. The occurrence of good-quality reservoir in the depth interval 3,000–3,800 m is diagenetically controlled with clay rims inhibiting quartz cementation and preserving excellent primary porosity. Development planning for Waitsia has commenced with the likelihood of an early production start-up utilising existing wells and gas processing facilities before ramp-up to full-field development. The dry gas will require minimal processing, and access to market is facilitated by the Dampier–Bunbury and Parmelia gas pipelines that pass directly above the field. The Waitsia Field is believed to be the largest conventional Australian onshore discovery for more than 30 years and provides impetus and incentive for continued exploration in mature and frontier basins. The presence of good-quality reservoir and effective fault seal was unexpected and emphasise the need to consider multiple geological scenarios and to test unorthodox ideas with the drill bit.

scholarly journals Development of the Foamer for Gas Wel Deliquification with a High Gas Condensate Content. Results of Application in the Conditions of Urengoyskoe Gas Field

2020 ◽  
Vol 127 (2) ◽  
pp. 20-24
Author(s):  
М. A. Silin ◽  
◽  
L. A. Magadova ◽  
Z. A. Shidginov ◽  
M. A. Cherigova ◽  
...  
Keyword(s):  
Gas Condensate ◽  
Gas Field

A Case History of Nitrogen Injection Monitoring in Rich Recycled Gas Condensate Reservoir, Onshore Gas Field, Abu Dhabi, UAE

2015 ◽  
Author(s):  
Hamza M. Hamza ◽  
Mahmood Al Suwaidi ◽  
Omar Al Jeelani ◽  
Arafat Al Yafei ◽  
Mahmoud Basioni ◽  
...  
Keyword(s):  
Case History ◽  
Gas Condensate ◽  
Abu Dhabi ◽  
Gas Field ◽  
Nitrogen Injection ◽  
Condensate Reservoir ◽  
History Of

Implementation of Multistack Sand Exclusion Methodology in Extremely Unconsolidated Wells: Learnings from Marginal Daman Field, Western Offshore India

2021 ◽  
Author(s):  
Ravindra M Patil ◽  
P V Murthy ◽  
Kutbuddin Bhatia ◽  
Mayur Deshpande ◽  
Karan Pande
Keyword(s):  
Success Factors ◽  
Gas Production ◽  
High Rate ◽  
High Stakes ◽  
Carrier Fluid ◽  
Packing Factor ◽  
Sand Control ◽  
Core Study ◽  
And Performance ◽  
Good Productivity

Abstract The Daman marginal field is a prolific gas-producing clastic field with highly unconsolidated Paleo-Miocene sandstone formations and a wide variety of lithologies across multistack sand layers. As such, high-rate water packs (HRWPs) are the ideal completion method in many Mumbai fields. Because multistack reservoirs require good zonal isolation, and to prevent crossflow between reservoirs with different pressure regimes, multistack sand exclusion (MSSE) methodology was selected for primary well completions with minimum rig time and a high degree of treatment placement accuracy. From an operational standpoint, exploiting these layers using this method means more control points can be achieved across these heterogeneous layers, and the MSSE completion is ideal for multiple applications in a shorter period, helping sustain sand-circumscribed gas production from these unconsolidated layers. During the design phase, grain-size distributions and core study defined the sand range from generally clean, coarse, and sorted to poorly sorted, with high-fines content and clay rich. To address the unique challenges of deep offshore operations, formation technical difficulties, high-stakes economics, and the significant untapped potential from these Daman sands, the MSSE approach was designed and implemented in this field. Historically, for multistack wells, an HRWP is performed zone by zone whereby the process of sump packer installation, perforation run, deburr run, screen assembly installation, and pumping is repeated for each zone. In Well A, the MSSE system was applied without any repetition and all in one phase. All layers were perforated and positively isolated. Each interval was individually opened for the HRWP treatment using a low-friction low-residue carrier fluid. Using a high-packing-factor proppant at a higher rate, the well was treated sequentially from the bottom of the interval to the top. Many marginal fields in this basin have become uneconomical because of the high cost and complexity of sand control methodology. Therefore, reducing costs and time becomes vital to help ensure economic viability, as well as achieving significant operational efficiencies. Additionally, reducing near-wellbore (NWB) mechanical skin and ensuring good productivity from the reservoir are among the major solutions when implementing an MSSE completion. The methodology adopted significantly helped reduce expenditures by standardizing completion design, simplifying the core complexity, and enhancing overall reliability and operational efficiency. The optimized engineering workflow was fit for purpose, rather than the conventional “cookie-cutter” method to address sanding propensity in this field. This paper discusses the cutting-edge MSSE completion systems that focused on downhole completion and modifications for pumping operations. Additionally, the paper reviews challenges addressed during this campaign, workflow adapted, detailed strategy success factors, and positive results obtained during evaluation. This has helped reduce potential risks and improve reliability and performance, which can act as best practices and can be applied within similar fields.

Achieving Cementing Improvement in Horizontal Tight Gas Field Development

2015 ◽  
Author(s):  
Pungki Ariyanto ◽  
Mohamed.A.. A. Najwani ◽  
Yaseen Najwani ◽  
Hani Al Lawati ◽  
Jochen Pfeiffer ◽  
...  
Keyword(s):  
Tight Gas ◽  
Cement Slurry ◽  
Tight Sandstone ◽  
Gas Field ◽  
Full Field ◽  
Field Development ◽  
Horizontal Drain ◽  
Tight Reservoir ◽  
Design For All ◽  
Zonal Isolation

Abstract This paper outlines how a drilling team is meeting the challenge of cementing a production liner in deep horizontal drain sections in a tight sandstone reservoir. It is intended to show how the application of existing technologies and processes is leading to performance gain and improvements in cementing quality. The full field development plan of the tight reservoir gas project in the Sultanate of Oman is based on drilling around 300 wells targeting gas producing horizons at measured depths of around 6,000m MD with 1,000m horizontal sections. Effective cement placement for zonal isolation is critical across the production liner in order to contain fracture propagation in the correct zone. The first few attempts to cement the production liner in these wells had to overcome many challenges before finally achieving the well objectives. By looking at the complete system, rather than just the design of the cement slurry, the following criteria areas were identified: –Slurry design–Mud removal and cement slurry placement–Liner hanger and float equipment Improvements have been made in each of these areas, and the result has been delivery of a succesfully optimised liner cementing design for all future horizontal wells.

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