scholarly journals Effect of Slot Width and Density on Slotted Liner Performance in SAGD Operations

Energies ◽  
2020 ◽  
Vol 13 (1) ◽  
pp. 268
Author(s):  
Yujia Guo ◽  
Alireza Nouri ◽  
Siavash Nejadi
Keyword(s):  
Large Scale ◽  
Control Method ◽  
Slot Width ◽  
Control Technique ◽  
Sand Production ◽  
Fines Migration ◽  
Pressure Drops ◽  
Sand Control ◽  
Mechanical Methods ◽  
Triaxial Cell

Sand production from a poorly consolidated reservoir could give rise to some severe problems during production. Holding the load bearing solids in place is the main goal of any sand control technique. The only sand control techniques that have found applications in steam assisted gravity drainage (SAGD) are some of the mechanical methods, including wire wrapped screens, slotted liners and more recently, punched screens. Slotted liner is one of the most effective mechanical sand control methods in the unconsolidated reservoir exploitation, which has proven to be the preferred sand control method in the SAGD operations. The main advantage of the slotted liners that makes them suitable for SAGD operations is their superior mechanical integrity for the completion of long horizontal wells. This study is an attempt to increase the existing understanding of the fines migration, sand production, and plugging tendency for slotted liners by using a novel large-scale scaled completion test (SCT) facility. A triaxial cell assembly was used to load sand-packs with specified and controlled grain size distribution, shape and mineralogy, on multi-slot sand control coupons. Different stress levels were applied parallel and perpendicular to different combinations of slot width and density in multi-slot coupons, while brine was injected from the top of the sand-pack towards the coupon. At each stress level, the mass of produced sand was measured, and the pressure drops along the sand-pack and coupon were recorded. Fines migration was also investigated by measuring fines/clay concentration along the sand-pack. The current study employed multi-slot coupons to investigate flow interactions among slots and its effect on the flow performance of liner under typically encountered stresses in SAGD wells. According to the experimental observations, increasing slot width generally reduces the possibility of pore plugging caused by fines migration. However, there is a limit for slot aperture beyond which the plugging is not reduced any further, and only a higher level of sanding occurs. Test measurements also indicated that besides the slot width, the slot density also influences the level of plugging and sand production and must be included in the design criteria.

Research on a New Type of Lithium Battery String Equalization and Management System

2011 ◽  
Vol 383-390 ◽  
pp. 1470-1476
Author(s):  
Hao Wang ◽  
Ding Guo Shao ◽  
Lu Xu
Keyword(s):  
Lithium Batteries ◽  
Management System ◽  
Lithium Battery ◽  
Large Scale ◽  
Control Method ◽  
Balance Control ◽  
Industrial Applications ◽  
Control Technique ◽  
New Type ◽  
Management Functions

Lithium battery has been employed widely in many industrial applications. Parameter mismatches between lithium batteries along a series string is the critical limits of the large-scale applications in high power situation. Maintaining equalization between batteries is the key technique in lithium batteries application. This paper summarizes normal equalization techniques and proposed a new type of lithium Battery Equalization and Management System (BEMS) employing the isolated DC-DC converter structure. The system is integrated both equalization functions and management functions by using distributed 3-level controlled structure and digital control technique. With this control method the flexibility of the balance control strategy and the compatibility for different battery strings are both improved dramatically. The experimental results show optimizing equalization, efficiency and the battery string life span has been extended.

Real-Time Prediction of Choke Health Using Production Data Integrated with AI

2021 ◽  
Author(s):  
Ahmed Alghamdi ◽  
Olakunle Ayoola ◽  
Khalid Mulhem ◽  
Mutlaq Otaibi ◽  
Abdulazeez Abdulraheem
Keyword(s):  
High Pressure ◽  
Real Time ◽  
Large Scale ◽  
Production Systems ◽  
Rate Of Change ◽  
Production Data ◽  
Ann Model ◽  
Sand Production ◽  
Data Set ◽  
Pressure Drops

Abstract Chokes are an integral part of production systems and are crucial surface equipment that faces rough conditions such as high-pressure drops and erosion due to solids. Predicting choke health is usually achieved by analyzing the relationship of choke size, pressure, and flow rate. In large-scale fields, this process requires extensive-time and effort using the conventional techniques. This paper presents a real-time proactive approach to detect choke wear utilizing production data integrated with AI analytics. Flowing parameters data were collected for more than 30 gas wells. These wells are producing gas with slight solids production from a high-pressure high-temperature field. In addition, these wells are equipped with a multi-stage choke system. The approach of determining choke wear relies on training the AI model on a dataset constructed by comparison of the choke valve rate of change with respect to a smoother slope of the production rate. If the rate of change is not within a tolerated range of divergence, an abnormal choke behavior is detected. The data set was divided into 70% for training and 30% for testing. Artificial Neural Network (ANN) was trained on data that has the following inputs: gas specific gravity, upstream & downstream pressure and temperature, and choke size. This ANN model achieved a correlation coefficient above 0.9 with an excellent prediction on the data points exhibiting normal or abnormal choke behaviors. Piloting this application on large fields, where manual analysis is often impractical, saves a substantial man-hour and generates significant cost-avoidance. Areas for improvement in such an application depends on equipping the ANN network with long-term production profile prediction abilities, such as water production, and this analysis relies on having an accurate reading from the venturi meters, which is often the case in single-phase flow. The application of this AI-driven analytics provides tremendous improvement for remote offshore production operations surveillance. The novel approach presented in this paper capitalizes on the AI analytics for estimating proactively detecting choke health conditions. The advantages of such a model are that it harnesses AI analytics to help operators improve asset integrity and production monitoring compliance. In addition, this approach can be expanded to estimate sand production as choke wear is a strong function of sand production.

scholarly journals A Solution to Sand Production from Natural Gas Hydrate Deposits with Radial Wells: Combined Gravel Packing and Sand Screen

2022 ◽  
Vol 10 (1) ◽  
pp. 71
Author(s):  
Yiqun Zhang ◽  
Wei Wang ◽  
Panpan Zhang ◽  
Gensheng Li ◽  
Shouceng Tian ◽  
...  
Keyword(s):  
Natural Gas ◽  
Gas Hydrate ◽  
Control Method ◽  
Gas Production ◽  
Sand Production ◽  
Natural Gas Hydrate ◽  
Vertical Well ◽  
Sand Control ◽  
Gravel Packing ◽  
Radial Well

Sand production is one of the main problems restricting the safe, efficient and sustainable exploitation of marine natural gas hydrate. To explore the sand-control effects of gravel packing, experiments that simulate hydrate extraction in the water-rich environment were conducted with designed hydrate synthesis and exploitation devices. Three sand control completion methods, including 120 mesh sand screen, 400 mesh sand screen, 120 mesh sand screen combined with gravel packing, are adopted. Sand and gas production rates were compared under different well types and sand control completion methods. Results show that the gas production modes of radial wells and vertical wells are almost the same at the same time due to the small experimental scale and high permeability. The sand production of the vertical well with gravel packing combined with a sand-control screen is 50% lower than that of the vertical well with sand-control screens only. Radial well with gravel packing combined with sand-control screens produced 87% less sand than screen mesh alone. The cumulative gas production and recovery rates of a radial well with the composite sand control method are better than those without gravel packing in the same development time.

Evaluation of Latest Technological Advances in Sand Control Completions: A Case Study

2021 ◽  
Author(s):  
Rishabh Bharadwaj ◽  
Manish Kumar ◽  
Shashwat Harsh ◽  
Deepak Mishra
Keyword(s):  
Oil And Gas ◽  
Control Method ◽  
Control Mechanisms ◽  
Sand Production ◽  
Production Rates ◽  
Reservoir Properties ◽  
Water Contact ◽  
Technological Advances ◽  
Sand Control ◽  
Gravel Pack

Abstract Sand control poses huge financial loses during production operations particularly in mature fields. It hinders economic oil production rates as well as damages downhole and surface equipment due to its abrasive action. Excessive sand production rates can plug the wellhead, flow lines, and separators which can result in detrimental well control situations. This paper will provide a comparative study on various sand control mechanisms by reviewing the latest advancements in sand management techniques. This study evaluates the performance of through-tubing sand screens, internal gravel pack, cased hole expandable sand screen, modular gravel pack system, openhole standalone screen, multi-zone single trip gravel pack, slim gravel pack, and chemical sand consolidation mechanisms. Various field examples from Niger-Delta, Mahakam oil and gas block, and offshore Malaysia are examined to gain an insight about the application of aforementioned sand control methods for different type of reservoirs. This study enables the operator to tackle the sand production problem according to the well construction changes during the life cycle of a well. The internal gravel pack completion system delivers a prolonged plateau production regime in shallow depths. In high drawdown conditions, chemical sand consolidation completion incurs early water breakthrough and elevated sand production. Chemical sand consolidation technique yields better results in deeper formations and its placement can be improvised by implementing coiled tubing and diversion techniques for multi-stage treatments. Depending on the well inclination, gas-water contact, producing zone type and thickness, well age, and economy, the completion types out of modular gravel pack, openhole standalone screen, slim gravel pack, and through tubing sand screen is recommended accordingly. Acquiring offset data, well log analysis, particle size distribution and performing pressure tests will improve the data quality of the obtained reservoir properties. This will further help in the selection of the most suitable sand control method for the target reservoir.

Extending Gravel Pack Carrier Fluid Performance in Highly Deviated Well for 7-Inch Gravel Pack Completion without Shunt Tube by Using High Grade Suspension Gravel Pack Fluid in Mahakam Offshore

2021 ◽  
Author(s):  
Putu Yudis ◽  
Doffie Cahyanto Santoso ◽  
Edo Tanujaya ◽  
Kristoforus Widyas Tokoh ◽  
Rahmat Sinaga ◽  
...  
Keyword(s):  
Control Method ◽  
Oil And Gas Industry ◽  
High Rate ◽  
Control Treatment ◽  
High Grade ◽  
Sand Production ◽  
Worst Case ◽  
Carrier Fluid ◽  
Sand Control ◽  
Gravel Pack

Abstract In unconsolidated sand reservoirs, proper sand control completion methods are necessary to help prevent reservoir sand production. Failure due to sand production from surface equipment damage to downhole equipment failures which can ultimately result in loss of well integrity and worst-case catastrophic failure. Gravel Packing is currently the most widely used sand control method for controlling sand production in the oil and gas industry to deliver a proppant filter in the annular space between an unconsolidated formation and a centralized integrated screen in front of target zones. Additional mechanical skin and proper proppant packing downhole are the most critical objective when implementing gravel packs as part of a completion operation. This paper presents a case history of Well SX that was designed as single-trip multi-zone completion 7-inch casing, S-shape well type, having 86 deg inclination along 1300 meters, 4 to 5-meter perforation range interval and 54 deg inclination in front of the reservoir with total depth of 3800 mMD. The well consists of 4 zones of interest which had previously been treated with a two-trip gravel pack system. While Well NX was designed as single-trip multi-zone completion in 7-inch casing, J-shape well type, 8-meter perforation interval and 84 deg inclination in front of the reservoir with total depth of 3300 mMD. The well consists of two zones of interest which had previously been treated with a single-trip gravel pack system. Both wells are in the Sisi-Nubi field offshore Mahakam on East Kalimantan Province of Borneo, Indonesia. This paper discusses the downhole completion design and operation as well as the changes to the gravel pack carrier which overcame challenges such as high friction in the 7" lower completion and the potential for an improper annular gravel pack due to the lack of shunt tubes in a highly deviated wellbore. In vertical wellbores, obtaining a complete annular pack is relatively easy to accomplish but in highly deviated wellbores, the annular gravel pack is more difficult to achieve and can contribute additional skin. Tibbles at al (2007) noted that installing a conventional gravel pack could result in skin values of 40 to 50, mostly due to poor proppant packing in perforation tunnels. Therefore, operator required to find a reliable gravel pack carrier fluid optimization for typical highly deviated wells to overcome the potential sand production issues by applying a single-trip multi-zone sand control system across both zones (without shunt tubes) along with the utilization of a high-grade xanthan biopolymer gravel pack carrier fluid. Laboratory testing was conducted to ensure that the gravel pack fluid could transport the sand to the sand control completion, large enough to allow for a complete annular pack and still allow the excess slurry to be circulated out of the hole. Electronic gravel pack simulations were performed to ensure that rate/pressure/sand concentration would allow for a complete gravel pack. All four zones in Both of Well SX and NX were successfully gravel packed with a high rate, relatively high sand concentration slurry. The well has not exhibited any sand production issues to date. The current production from both wells is above expectation and are comingled from the two primary zones. Multiple factors were considered during the design and operation of the sand control treatment. Those factors will be described in this paper, starting with candidate selection, completion strategy, operational challenges and treatment execution along with production monitoring of the well.

Hanging Screen Evaluation to Unlock Marginal Sandy Reservoir: Case Study of Peciko Gas Field, Indonesia

2021 ◽  
Author(s):  
Danny Hidayat ◽  
Rantoe Marindha ◽  
Triantoro Ade Nugroho ◽  
Reyhan Hidayat ◽  
Runi Kusumaning Rusdi
Keyword(s):  
Control Method ◽  
Low Cost ◽  
Sand Production ◽  
Liquid Loading ◽  
Control Cost ◽  
Gas Field ◽  
Production Phase ◽  
Sand Control ◽  
And Performance ◽  
Shallow Reservoirs

Abstract Peciko Field currently produces gas from multilayer sand-prone shallow reservoirs. Therefore, it needs sand control method to unlock these marginal reservoirs through low-cost intervention. Hanging screen has been reviewed as an alternative solution to minimize sand control cost while maintaining its robustness to maximize the recovery. This paper will present and evaluate the hanging screen installation and performance from subsurface to surface elements in Peciko field. Hanging screen implementation in Peciko will be evaluated in terms of ease of installation to its performance during production phase. Peciko wells are equipped with real-time monitoring system including Acoustic Sand Detector. Therefore, sand problems could be easily identified. Any indication of screen failure will be confirmed by checking the surface equipment like chokes and intrusive probes. Further intervention to retrieve the screen and perform visual check at surface can be executed to extend the verification. Filter size, placement method, clean-up, and sand sieve result will be gathered to identify the root cause and determine the best method to apply hanging screen as reliable sand control method. Nine installations in 2019 conclude that screen plugging, liquid loading, and combination of both are main issues in production phase. With three plugging cases from well Fx and E2x, it was found that excessive drawdown pressure triggers high gas velocity in perforation tunnel and causing excessive sand production that plugged the screen. These cases also prove that self-unloading by choke movement can lead to plugging if the drawdown pressure and gas rate are not monitored carefully. Commingle production in Ax becomes an issue in lifting performance when reservoir pressure declines and liquid was produced from several reservoirs. Limiting drawdown pressure gives smaller gas rate to lift the liquid and make the well died from liquid loading easily. Massive sand production in well E2x and E2y cause an increase in Top of Sediment (TOS) and lead to inaccessible screen even with multiple bailing attempts. A series of screen design, choke configuration, proper clean-up and continuous monitoring are critical steps to be performed prior and after screen installation to maintain production lifetime. With average stakes of 0.2 Bcf per well, hanging screen has proven to produce 67% of the well reserves in shallow reservoirs. This value creation led to the conclusion that hanging screen is an economically-feasible-sand control method to be implemented in Peciko.

scholarly journals Experimental Study of Sand Production during Depressurization Exploitation in Hydrate Silty-Clay Sediments

Energies ◽  
2019 ◽  
Vol 12 (22) ◽  
pp. 4268 ◽  
Author(s):  
Jingsheng Lu ◽  
Dongliang Li ◽  
Yong He ◽  
Lingli Shi ◽  
Deqing Liang ◽  
...  
Keyword(s):  
Large Scale ◽  
Silty Clay ◽  
Sand Production ◽  
Fracture Permeability ◽  
Vertical Wells ◽  
Mud Cake ◽  
Water Rates ◽  
Sand Control ◽  
Production Temperature ◽  
Clay Sediment

Silty-clay reservoirs are a weak point in sand production and sand control studies due to their low economy. However, China’s marine natural gas hydrates (NGH) mostly exist in silty-clay sediments, which restrict the sustainable and efficient development of NGH. In order to study the sand production of hydrate silty-clay sediments, hydrate production experiments in vertical wells and horizontal wells were carried out using a self-developed hydrate sand production and sand control simulation device. The results showed a great difference between the hydrate silty-clay sediments and hydrate sand sediments. The significant differences in production pressure and production temperature between the different layers indicated the low permeability and low heterogeneity of the hydrate silty-clay sediments. The sliding settlement of the overall depression in the horizontal well and overall subsidence in the vertical well of the hydrate silty-clay reservoir would easily lead to silty-clay flow and large-scale sand production. When water rates decreased, the property of “silty-clay sediment filtration and wall building” was found, which formed a “mud cake” around the wellbore. The good strength of adhesion and fracture permeability of the “mud cake” provided ideas for reservoir reformation. This study further discusses sand production and sediment reformation in hydrate silty-clay sediments.

scholarly journals Laboratory Investigation on Optimum Selection of a Sand Control Method for an Interbedded Sandstone and Mudstone Reservoir

Geofluids ◽  
2020 ◽  
Vol 2020 ◽  
pp. 1-10
Author(s):  
Shaofeng Hu ◽  
Lihua Wang ◽  
Yishan Lou ◽  
Yanfeng Cao ◽  
Wenbo Meng ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Control Method ◽  
Experimental Studies ◽  
Control Design ◽  
Gas Production ◽  
Control Mode ◽  
Critical Parameters ◽  
Bohai Bay ◽  
Sand Production ◽  
Sand Control

It is critical to select an optimized sand control method for an interbedded sandstone and mudstone reservoir (ISMR) due to its serious sand production hazards. However, currently, most general sand control methods cannot meet the requirements of sand control in interbedded sandstone and mudstone reservoirs (e.g., Bohai Bay oil and gas fields from China). Ensuring efficiency of sand control and increasing the oil and gas production rate in this interbedded sandstone and mudstone become more and more important. In this paper, a “multilayer rotatable sand control experimental device” for the interbedded sandstone and mudstone reservoir was developed. A series of sand control experimental studies were conducted by using the proposed device. The net-to-gross ratio (NTG) and well inclinations are two major factors considered in the experimental analysis. In addition, a sensitivity analysis regarding formation particle size distribution (PSD), clay content, and mineral compositions is performed in the experiment under a moderate sand control mode. With systematic experimental test results in this work, combined with numerous existing sand control models, a set of optimum sand control design and the associated optimization template for ISMR were developed, which have been successfully applied in Bohai Bay. Field application results show that NTG and well inclination are two critical parameters in the design of sand control in ISMR. The optimal indexes of a sand control mode are determined as NTG of 0.4 and well inclination of 45°. The introduction of these two key factors in sand control design broadens the application range of moderate sand production.

Characterization of Sand Production for Clayey-Silt Sediments Conditioned to Openhole Gravel-Packing: Experimental Observations

SPE Journal ◽  
2021 ◽  
pp. 1-18
Author(s):  
Yurong Jin ◽  
Yanlong Li ◽  
Nengyou Wu ◽  
Daoyong Yang
Keyword(s):  
Large Scale ◽  
Early Stage ◽  
Tensile Failure ◽  
Inlet Pressure ◽  
Sand Production ◽  
Failure Patterns ◽  
Sand Control ◽  
Clayey Silt ◽  
Fracture Development ◽  
Gravel Packing

Summary As one of the geotechnical risks, sanding has been one of the main constraints for safely and sustainably developing marine natural gas hydrate. In this study, a cylindrical vessel that is packed with the clayey-silt sediment collected from the Shenhu area of the northern South China Sea is used to microscopically observe sand detachment, migration within matrix, invasion to gravel packing, and production for openhole gravel packing. More specifically, by injecting water from the vessel boundary, the seepage and stress-strain field for sediment near the wellbore after hydrate dissociation is simulated, and the sand failure characteristics [i.e., the produced sand volume and particle size distributions (PSDs)] are quantified. The sand failure pattern is found to largely differ from that of a sandstone reservoir, whereas fractures, wormholes, and fluidized channels are successively developed along with a large scale of sand production and inlet pressure variation. Followed is a steady flow state with a stable inlet pressure without noticeable sand failure. Correspondingly, the fracture is induced and propagated by the combinational effort of shear and tensile failure, whereas wormholes and fluidized channels are associated with the liquid dragging force. At the end of each test, foraminifera are found to accumulate near the external side of the gravel-packing region, which is beneficial to sand control. In the meantime, a compact mudcake, as an infiltration medium, is observed outside the gravel-packing layer. The 30/50 mesh gravel packing is able to control grain size up to 30.0 µm in diameter with a median of 5.0 µm, whereas the produced grains account for less than 1.0 vol% of the total sediment. By performing sensitivity analysis on sand production, depressurization shall be conducted at a small rate to not only control sand production, but also to induce flow paths at the early stage. Moreover, the sand production rate associated with fracture development is larger than those of wormholes and fluidized channels. This study focuses on the experimental observations on sand failure patterns, and the theoretical formulations and modeling will be presented and explained in a future work.3

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