Optimized Completions Design Using Retrofit Autonomous Inflow Control Devices

2021 ◽  
Author(s):  
Ezinne Amanda Nnebocha ◽  
Akinola Akinbola ◽  
Omagbemi George Kakayor ◽  
Adetayo Odutayo ◽  
Tunji Olukayode ◽  
...  
Keyword(s):  
Real Time ◽  
High Water ◽  
Reservoir Model ◽  
Production Forecast ◽  
Start Up ◽  
Stock Tank ◽  
Sand Control ◽  
Control Devices ◽  
High Water Cut ◽  
Water Cut

Discovered in 1964, the Beta Field in the Niger Delta sedimentary basin consists of 25 stacked hydrocarbon-bearing reservoirs located between 5,500 and 12,000 feet true vertical depth subsea (TVDSS). A total of 26 wells have been drilled in the field, of which 11 are presently on production. Oil production peaked at 8,900 stock-tank barrels per day shortly after field start-up and has been on the decline. More than 40 years since production start-up, the Beta Field remains a relatively immature, distinctly underdeveloped asset. Only about 59 million stock tank barrel (STB), or 8% of its estimated stock-tank oil initially in place of 740 million STB, had been produced by the end of 2017. Two horizontal wells were planned in the field to provide additional drainage points and increase field production. However, a production forecast of the planned wells showed potential early water breakthrough and high water cut because of unfavorable mobility ratios of a slightly viscous oil and proximity to oil/water contact (OWC). To mitigate the production challenges and improve the reservoir sweep, autonomous inflow control devices (AICDs) were selected to be installed on the sandface completion. These wells were drilled and completed during the COVID-19 pandemic, bringing additional challenges in equipment availability and logistics with potential to derail the successful completion of these wells within the required timeline. An innovative retrofit screen design, leveraging detailed engineering design and remote collaboration, enabled the conversion of ICD sand control screens to cyclonic AICD screens. AICD nozzle placement was optimized using a reservoir-centric workflow that integrates the full reservoir model with the sandface completion. Real-time interpretation of the data enabled computation of porosity-permeability and saturation estimates from logging-while-drilling (LWD) logs, which was then used in updating the reservoir model in near-real time. Using a segmented well modeling approach and a refined flow distribution from heel to toe, AICD nozzle placement was optimized in real time utilizing LWD measurements from open hole along the horizontal drain, aiding the design and configuration of the AICDs. The Beta-7 and Beta-8 wells were successfully drilled, completed, and put on production. The horizontal drains were landed within 5 to 10 feet of the top of the reservoir, maintaining at least 20-ft distance from the OWC. The forecasted simulation showed possible water influx from the toe of the horizontal as opposed to the heel because of existing water leg and high permeability at the toe. This was supported by high water-cut production from that zone in the nearby wells. This insight from the full-field simulation model enabled an informed decision on the AICD design.

Innovations of Gas Lift in Prolific, Long-perforations, and Multilayered Wells, Case Study in Sudan

2016 ◽  
Author(s):  
Xueqing Tang ◽  
Lirong Dou ◽  
Ruifeng Wang ◽  
Jie Wang ◽  
Shengbao Wang ◽  
...  
Keyword(s):  
High Water ◽  
Water Breakthrough ◽  
Start Up ◽  
Production Wells ◽  
Decline Curves ◽  
High Water Cut ◽  
Water Cut ◽  
Gas Lift

ABSTRACT Jake field, discovered in July, 2006, contains 10 oil-producing and 12 condensate gas-producing zones. The wells have high flow capacities, producing from long-perforation interval of 3,911 ft (from 4,531 to 8,442 ft). Production mechanisms include gas injection in downdip wells and traditional gas lift in updip, zonal production wells since the start-up of field in July, 2010. Following pressure depletion of oil and condensate-gas zones and water breakthrough, traditional gas-lift wells became inefficient and dead. Based on nodal analysis of entire pay zones, successful innovations in gas lift have been made since March, 2013. This paper highlights them in the following aspects: Extend end of tubing to the bottom of perforations for commingled production of oil and condensate gas zones, in order to utilize condensate gas producing from the lower zones for in-situ gas lift.Produce well stream from the casing annulus while injecting natural gas into the tubing.High-pressure nitrogen generated in-situ was used to kick off the dead wells, instead of installation of gas lift valves for unloading. After unloading process, the gas from compressors was injected down the tubing and back up the casing annulus.For previous high water-cut producers, prior to continuous gas lift, approximately 3.6 MMcf of nitrogen can be injected and soaked a couple of days for anti-water-coning.Two additional 10-in. flow lines were constructed to minimize the back pressure of surface facilities on wellhead. As a consequence, innovative gas-lift brought dead wells back on production, yielding average sustained liquid rate of 7,500 bbl/d per well. Also, the production decline curves flattened out than before.

A Successful Application of Continuous Pack-Off Technology to Water Shutoff Recompletion for High-WCT Gravel-Packed Horizontal Well

2021 ◽  
Author(s):  
An Jiang ◽  
Yunpeng Li ◽  
Xing Liu ◽  
Fengli Zhang ◽  
Tianhui Wang ◽  
...  
Keyword(s):  
Horizontal Well ◽  
Axial Flow ◽  
High Water ◽  
Bohai Bay ◽  
Horizontal Section ◽  
Well Completion ◽  
Water Shutoff ◽  
Sand Control ◽  
High Water Cut ◽  
Water Cut

Abstract Objectives/Scope Controlling the excessive water production from the high water cut gravel packing horizontal well is a challenge. The approach which uses regular packers or packers with ICD screens to control the unwanted water does not function well. This is mainly because of the length limitation of packers which will make the axial flow resistance insufficient. Methods, Procedures, Process In this paper, a successful case that unwanted water is shutoff by using continuous pack-off particles with ICD screens (CPI) in the whole horizontal section in an offshore oilfield of Bohai bay is presented. The reservoir of this case is the bottom-water high viscosity reservoir. The process is to run 2 3/8" ICD screen string into the 4" screen string originally in place, then to pump the pack-off particles into the annulus between the two screens, and finally form the 360m tightly compacted continuous pack-off particle ring. Results, Observations, Conclusions The methodology behind the process is that the 2-3/8" ICD screens limit the flow rate into the pipes as well as the continuous pack-off particle ring together with the gravel ring outside the original 4" screens to prevent the water channeling into the oil zone along the horizontal section. This is the first time this process is applied in a high water cut gravel packed horizontal well. After the treatment, the water rate decreased from 6856BPD to 836.6BPD, the oil rate increased from 44BPD to 276.8BPD. In addition, the duration of this performance continued a half year until March 21, 2020. Novel/Additive Information The key of this technology is to control the unwanted water by using the continuous pack-off particles instead of the parkers, which will bring 5 advantages, a) higher efficiency in utilizing the production interval; b) no need to find the water source and then fix it; c) the better ability to limit the axial flow; d) effective to multi-WBT (water break though) points and potential WBT points; e) more flexible for further workover. The technology of this successful water preventing case can be reference to other similar high water cut gravel packed wells. Also, it has been proved that the well completion approach of using CPI can have good water shutoff and oil incremental result. Considering the experiences of historical applications, CPI which features good sand control, water shutoff and anti-clogging is a big progress compared to the current completion technologies.

Implementation of TAML Level#4 Multilateral with Gravel Packed Lateral Leg to Solve Field Production Challenges

2021 ◽  
Author(s):  
Jin Li ◽  
Kunjian Wang ◽  
HaiNing Chen ◽  
Nigel Ruescher ◽  
Ruicheng Pang ◽  
...  
Keyword(s):  
High Water ◽  
Oil Field ◽  
Development Cost ◽  
Technology Advancement ◽  
Sand Control ◽  
Open Hole ◽  
High Water Cut ◽  
Water Cut ◽  
Offshore Oil ◽  
Gravel Pack

Abstract An offshore oil field in China was experiencing production challenges due to high water cut and low overall production. In order to boost production and address these challenges, adjacent reservoirs would need to be accessed and developed. Application of multilateral completion technology was considered the best method to achieve this, saving platform slots, increasing reservoir contact and keeling development cost low. An integrated solution was provided that allowed Technology Advancement Multilateral (TAML) Level#4 Multilateral Junctions with Gravel Packed Lateral sections, the first application of this type in China. The existing mainbore was temporarily isolated. Casing Exit was conducted at designated setting, and Hook Hanger TAML Level#4 Multilateral junction system was successfully installed and cemented. The horizontal Lateral bore was subsequently entered and gravel pack operations were successfully performed. Hydraulic integrity along well string is key to successful horizontal open hole gravel pack(OHGP). This TAML level#4 Multilateral completion design provided hydraulic integrity at junction during the whole OHGP process, the key to successful gravel pack. The mainbore can be restored as required. This paper concentrates on the technology utilized to successfully complete these wells. Multilateral and Gravel Pack equipment, challenges and solutions that were deployed to make this project a success are outlined. Three old wells in the field have applied this technology and have successfully improved production by 200m3/d. The wells give ability to selectively produce or comingle, allowing more flexibility with production. The introduction of Gravel Pack into the lateral affords greater sand control capabilities and ultimately assists overall production in well life. This application is now field proven with demonstrated production benefits and has potential for implementation in more developments in the region in future.

Preventing Proppant and Formation-Sand Production in High Water Cut, Heavy-Oil Wells: A Field Study from Argentina

2009 ◽  
Author(s):  
Daniel Daparo ◽  
Luis Soliz ◽  
Eduardo Roberto Perez ◽  
Carlos Iver Vidal Saravia ◽  
Philip Duke Nguyen ◽  
...  
Keyword(s):  
Field Study ◽  
Heavy Oil ◽  
High Water ◽  
Oil Wells ◽  
Sand Production ◽  
High Water Cut ◽  
Water Cut
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