Sand Free Production Success Through Proven Technology Enabler from An Untapped Heterogeneous Reservoir Zone Utilizing Gravel Pack Replacement Methodology

2020 ◽  
Author(s):  
Y. Anggoro
Keyword(s):  
Oil And Gas ◽  
Erosion Resistance ◽  
Cost Effective ◽  
High Rate ◽  
Screen Design ◽  
Sand Control ◽  
Rules Of Thumb ◽  
Production Success ◽  
Control Technologies ◽  
Gravel Pack

The Belida field is an offshore field located in Block B of Indonesia’s South Natuna Sea. This field was discovered in 1989. Both oil and gas bearing reservoirs are present in the Belida field in the Miocene Arang, Udang and Intra Barat Formations. Within the middle Arang Formation, there are three gas pay zones informally referred to as Beta, Gamma and Delta. These sand zones are thin pay zones which need to be carefully planned and economically exploited. Due to the nature of the reservoir, sand production is a challenge and requires downhole sand control. A key challenge for sand control equipment in this application is erosion resistance without inhibiting productivity as high gas rates and associated high flow velocity is expected from the zones, which is known to have caused sand control failure. To help achieve a cost-effective and easily planned deployment solution to produce hydrocarbons, a rigless deployment is the preferred method to deploy downhole sand control. PSD analysis from the reservoir zone suggested from ‘Industry Rules of Thumb’ a conventional gravel pack deployment as a means of downhole sand control. However, based on review of newer globally proven sand control technologies since adoption of these ‘Industry Rules of Thumb’, a cost-effective solution could be considered and implemented utilizing Ceramic Sand Screen technology. This paper will discuss the successful application at Block B, Natuna Sea using Ceramic Sand Screens as a rigless intervention solution addressing the erosion / hot spotting challenges in these high rate production zones. The erosion resistance of the Ceramic Sand Screen design allows a deployment methodology directly adjacent to the perforated interval to resist against premature loss of sand control. The robust ceramic screen design gave the flexibility required to develop a cost-effective lower completion deployment methodology both from a challenging make up in the well due to a restrictive lubricator length to the tractor conveyancing in the well to land out at the desired set depth covering the producing zone. The paper will overview the success of multi-service and product supply co-operation adopting technology enablers to challenge ‘Industry Rules of Thumb’ replaced by rigless reasoning as a standard well intervention downhole sand control solution where Medco E&P Natuna Ltd. (Medco E&P) faces sand control challenges in their high deviation, sidetracked well stock. The paper draws final attention to the hydrocarbon performance gain resulting due to the ability for choke free production to allow drawing down the well at higher rates than initially expected from this zone.

Lessons Learned from the First Chemical Sand Consolidation in Zawtika Field

2021 ◽  
Author(s):  
Wiwat Wiwatanapataphee ◽  
Thanita Kiatrabile ◽  
Pipat Lilaprathuang ◽  
Noppanan Nopsiri ◽  
Panyawadee Kritsanamontri
Keyword(s):  
Control Method ◽  
Cost Effective ◽  
Lessons Learned ◽  
Candidate Selection ◽  
High Rate ◽  
Operation Performance ◽  
Coiled Tubing ◽  
Cost Effective Method ◽  
Sand Control ◽  
Gravel Pack

Abstract The conventional gravel pack sand control completion (High Rate Water Pack / Extension Pack) was the primary sand control method for PTTEPI, Myanmar Zawtika field since 2014 for more than 80 wells. Although the completion cost of gravel pack sand control was dramatically reduced around 75 percent due to the operation performance improvement along 5 years, the further cost reduction still mandatory to make the future development phase feasible. In order to tackle the well economy challenge, several alternative sand control completion designs were reviewed with the existing Zawtika subsurface information. The Chemical Sand Consolidation (CSC) or resin which is cost-effective method to control the sand production with injected chemicals is selected to be tested in 3 candidate wells. Therefore, the first trial campaign of CSC was performed with the Coiled Tubing Unit (CTU) in March to May 2019 with positive campaign results. The operation program and lesson learned were captured in this paper for future improvement in term of well candidate selection, operation planning and execution. The three monobore completion wells were treated with the CSC. The results positively showed that the higher sand-free rates can be achieved. The operation steps consist of 1) Perform sand cleanout to existing perforation interval or perforate the new formation interval. 2) Pumping pre-flush chemical to conditioning the formation to accept the resin 3) Pumping resin to coating on formation grain sand 4) Pumping the post-flush chemical to remove an excess resin from sand 5) Shut in the well to wait for resin curing before open back to production. However, throughout the campaign, there were several lessons learned, which will be required for future cost and time optimization. In operational view, the proper candidate selection shall avoid operational difficulties e.g. available rathole. As well, detailed operation plan and job design will result in effective CSC jobs. For instance, the coil tubing packer is suggested for better resin placement in the formation. Moreover, accommodation arrangement (either barge or additional vessel) and logistics management still have room for improvement. These 3 wells are the evidences of the successful applications in Zawtika field. With good planning, lesson learned and further optimization, this CSC method can be beneficial for existing monobore wells, which required sand control and also will be the alternative sand control method for upcoming development phases. This CSC will be able to increase project economic and also unlock the marginal reservoirs those will not justify the higher cost of conventional gravel pack.

Well-Flux Surveillance and Ramp-Up Method for Openhole Standalone Screen Completion

2021 ◽  
Vol 73 (03) ◽  
pp. 53-54
Author(s):  
Judy Feder
Keyword(s):  
Technical Conference ◽  
High Rate ◽  
Well Performance ◽  
University Of Houston ◽  
Surveillance Model ◽  
Sand Control ◽  
Operating Limits ◽  
Direct Linkage ◽  
Flux Model ◽  
Gravel Pack

This article, written by JPT Technology Editor Judy Feder, contains highlights of paper SPE 201662, “A Well-Flux Surveillance and Ramp-Up Method for Openhole Standalone Screen Completion,” by Mehmet Karaaslan and George K. Wong, University of Houston, and Kevin L. Soter, SPE, Shell, et al., prepared for the 2020 SPE Annual Technical Conference and Exhibition, originally scheduled to be held in Denver, Colorado, 5-7 October. The paper has not been peer reviewed. Production and surveillance engineers need practical models to help maximize production while avoiding ramping up the well to an extent that the completion is damaged, causing well impairment or failure. The complete paper presents a well-flux surveillance method to monitor and ramp up production for openhole standalone screen (OH-SAS) completions that optimizes production by considering risks of production impairment and screen-erosion failure. Challenges of Increased Production vs. Well Failure The problem of increased production vs. the risk of well impairment or failure is a pressing problem for sand-control wells in deepwater, where projects tend to have a small number of high-rate wells. In such environments, any well impairments or failures greatly affect the project economics. Following unloading, well surveillance faces the critical step of ramping up to-ward the well’s designed peak rate for the first time when the actual well performance is uncertain. To reduce risk of well impairment or failure, surveillance information and models are needed to help make adjustments during the ramp-up process. Different models are available, from simple to complex and from small to large amounts of input data and computational efforts. Simple nonsurveillance models use field-derived operating limits of completion pressure drop and flow velocity or flux. They are non-surveillance models in the sense that no direct linkage of surveillance results to update flux calculations exists. Simple surveillance models use pressure transient analysis (PTA) results and completion information to evaluate changing well performance and adjust the ramp-up and long-term surveillance operations. The complex surveillance model evaluates well performance and adjusts well operations using probabilistic completion failure risks and coupled reservoir and completion simulations. These models mainly focus on cased-hole gravel pack and frac-pack applications. For openhole completions with sand control, the literature offers limited ramp-up surveillance references. The objective of the well-flux model described in the complete paper is to ramp up the well safely and optimize production using PTA results as surveillance inputs to calculate completion fluxes for well impairment or failure assessment. The method follows an approach presented in the literature.

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.

Pipelines Industry in India: Recent Developments and Future Requirements

2002 ◽  
Author(s):  
Harsukh Parekh ◽  
Vipin Chandra Sati
Keyword(s):  
Natural Gas ◽  
Oil And Gas ◽  
Private Investment ◽  
Cost Effective ◽  
Petroleum Products ◽  
High Rate ◽  
Indian Government ◽  
Effective Manner ◽  
Recent Developments ◽  
Set Up

The consumption of petroleum products in India has been growing at a high rate. In order to meet the growing demand for petroleum, additional refining capacity is planned to be created involving augmentation of some of the existing refineries and construction of new refineries. While the refineries will be in a position to meet the demand of petroleum products, the critical and vital issue will be to supply crude oil to the refineries and to reach the products to various consumption centers in an efficient, reliable and cost effective manner. In addition to the liquid petroleum, Natural Gas is emerging as the major source of energy/feedstock. Infrastructure for storage and transportation of Natural Gas are also required to be set up in a big way to meet the projected demand. This can best be done by constructing new pipelines which are recognized worldwide as the most reliable and cost effective mode of transportation of oil and gas. In addition to the requirement for new pipelines, there is a need for upgradation of technology in the existing cross-country pipelines, many of which are more than 20 years old. Moreover, Indian Government has, as part of the process of liberalisation of the economy through a series of measures focused on the infrastructural developments, technology upgradation, trade policies and financial reforms, has opened the core sector of Petroleum to private investment. Thus, considerable scope exists not only for consultants, equipment and material manufacturers/suppliers and contractors for providing their services but also for making investments in the Indian pipeline industry. This paper describes the prospects/opportunities in the Indian pipeline industry.

One Trip 7" Multi Zone Gravel Pack System: Success Case and Learning Points from the First Installation in Malaysia

2021 ◽  
Author(s):  
M. Helmi Nordin ◽  
Ajmal Faliq Jamal ◽  
M. Helmie Hairi ◽  
Sunanda Magna Bela
Keyword(s):  
High Rate ◽  
Control Technique ◽  
Control Treatment ◽  
Design Factor ◽  
Carrier Fluid ◽  
Recent Success ◽  
Sand Control ◽  
The One ◽  
Gravel Pack ◽  
Selection Of

Abstract Main reservoirs in this brown field are designed with Cased Hole Gravel Pack (CHGP), which is a proven sand control technique in the area. Most multi-stack reservoirs in these wells require individual sand control treatment on each zone as the formation properties varies from one to another. One of the most recent success case was the installation of One Trip 7" Multi Zone System that enabled implementation of an optimized High Rate Water Pack sand control operation in the casing size. This new technique helps to make more multi zone CHGP in infill or sidetracked wells feasible and more economical. Previously, CHGP design in 7" casing was limited to stack pack design which means the steps of sump packer installation, perforation, deburr run, GP assembly installation and GP pumping have to be repeated for every zone. The repeated process was laborious and incurred a lot of cost due to the extensive rig time. With the new 7" one-trip design that evolved from the existing 9-5/8" system, the multiple zone GP treatment can be done in single trip and contributes to significantly reduced well cost. One of the design consideration that need to be focused on is selection of carrier fluid to ensure optimum carrying capability during proppant placement while reducing the pumping friction through the one trip system. Full coverage of screens and blanks was achieved for both zones that were completed with the One Trip 7" Multi Zone completion. Both zones were treated with hybrid pack that is combination of circulating and HRWP. The primary objectives on optimizing rig time were achieved in eliminating multiple runs for different zones, as well as reducing risks of multiple disengagement with lower assembly that adds difficulty during reverse-out operation. One of the key limitations of this system is the high friction pressure when pumping through long concentric wash pipes and this can affect the effectiveness during proppant reverse out, especially considering the burst rating of the casing as well. Due to this known restriction, cement have been designed and tested up to the anticipated annular pressure during reversing out operation. Another design factor that could also pose a challenge during operation is the limit of sand concentration that is 1 ppa and this again is due to concentric wash pipe design.

Comprehensive Transient Modeling of Sand Production in Horizontal Wellbores

SPE Journal ◽  
2007 ◽  
Vol 12 (04) ◽  
pp. 468-474 ◽  
Author(s):  
Alireza Nouri ◽  
Hans H. Vaziri ◽  
Hadi Arbi Belhaj ◽  
M. Rafiqul Islam
Keyword(s):  
Numerical Model ◽  
Significant Proportion ◽  
Horizontal Wells ◽  
Gas Production ◽  
Operating Conditions ◽  
High Rate ◽  
Sand Production ◽  
Predictive Tool ◽  
Sand Control ◽  
Gravel Pack

Summary Installing sand control in long horizontal wells is difficult and particularly challenging in offshore fields. It is, therefore, imperative to make decisions with regard to the most optimum completion type objectively and based on reliable assessment of the sanding potential and its severity over the life of the well for the intended production target. This paper introduces a predictive tool that forecasts not only the initiation of sanding, but also its rate and severity in real time. A series of well-documented experiments on a large-size horizontal wellbore was simulated using a finite difference numerical model. The model accounts for the interaction between fluid flow and mechanical deformation of the medium, capturing various mechanisms of failure. The model allows capturing the episodic nature of sanding and the resulting changes in the geometry and formation consistency and behavior within the sand impacted regions. Sand detachment is simulated by removal of the elements that are deemed to have satisfied the criteria for sanding based on considerations of physics, material behaviour and laws of mechanics. The proposed numerical model is designed to account for many of the factors and mechanisms that are known to influence sanding in the field and as such can be used as a practical tool for predicting the frequency and severity of sand bursts and changes in operating conditions that can be considered for mitigating or managing such problems. The model shows reasonable agreement with the experimental results in terms of borehole deformation and sanding rates. The model correctly predicted initiation of shear failure from the sides of the borehole and its propagation to the boundaries of the sample. It was further seen that the propagation of the shear failed zone resulting from sand production agreed well with the numerical pattern of failure growth upon removal of elements satisfying the sanding criteria. The approach and concepts used are considered suitable for application to field problems involving horizontal wells. Introduction A significant proportion of the future oil and gas production is expected to come from sand-prone reservoirs, many of which are offshore. While these reservoirs are highly prolific they are complex to develop and manage. Typical cost of completing a major offshore well exceeds $100 million and these wells are expected to remain productive for 20 years and longer. The control of solids production in these high-rate wells over the life of the well is a challenge and requires a good understanding of the mechanical behavior of the formation under a variety of conditions. Various options are available, ranging from placing active sand control, such as gravel pack and frac pack, to natural completion, such as a cased and perforated hole. Objectivity is required in choosing the correct completion type, which must account for the production strategy and natural changes in the reservoir such as changes in the stress state, permeability, and multiphase flow, including water cut. Once the completion type is chosen, it must be operated optimally to maximize production while maintaining efficiency and longevity. For instance, in sand-control completions, operations must be tailored to mitigate generation and transport of fines that can cause plugging of the gravel pack and lead to screen erosion, whereas in natural completions, the emphasis would be in preventing formation sand production or keeping it under the tolerance that can be handled by the facility. Utilization of a reliable sand production prediction tool is essential in selecting the optimum completion technique and optimization of the operational conditions.

Multizone Openhole Gravel Packing with Enhanced Shunt Screens and Zonal Isolation in High-Rate Gas Wells

2021 ◽  
Author(s):  
Ross Markham ◽  
Alastair Michell ◽  
David Noblett ◽  
Bernard McCartan ◽  
Septiandi Sugiarto ◽  
...  
Keyword(s):  
High Temperature ◽  
Capital Expenditure ◽  
High Rate ◽  
Successful Implementation ◽  
Operating Pressure ◽  
Carrier Fluid ◽  
Shunt Tube ◽  
Sand Control ◽  
Zonal Isolation ◽  
Gravel Pack

Abstract A reliable single-trip openhole multizone completion can significantly lower capital expenditure (CAPEX) by reducing rig time and well count. Recent improvements in openhole packers and enhanced shunt screen technology have enabled multizone openhole gravel pack completions with complete zonal isolation. A multizone openhole gravel-pack completion was installed in the Julimar Field with an enhanced shunt screen system, shunted mechnaical packers (SMP) and shunt tube isolation valves (STIV), to provide improved operating pressure envelope and erosion tolerance. Well design was tailored to derisk the installation and optimize performance of the multizone completion. Extensive reliability testing was undertaken on all new technology for this project. Completions were installed as planned, and the main objectives of sand control integrity, production attainment, and complete zonal isolation with selective production were validated through post-job gravel-pack analysis and subsequent well unloading. The successful implementation of these technologies significantly reduced project CAPEX and enabled access to reserves that would otherwise have been uneconomical to recover. This paper discusses design, execution, and evaluation of the multizone openhole gravel pack (OHGP) completions installed in the Julimar Field. This includes methodology followed for multizone completion selection, development of a new high-temperature formate-based viscous gravel-pack carrier fluid, detailed completion equipment qualification tests, post-job gravel-pack evaluation, and initial well performance from well unload. It is the industry's first field case study of enhanced shunt screens with novel shunt tube isolation valves and high-temperature xanthan-based gravel-pack carrier fluid.

Technology Focus: Sand Management (October 2021)

2021 ◽  
Vol 73 (10) ◽  
pp. 67-67
Author(s):  
Imran Abbasy
Keyword(s):  
Oil And Gas ◽  
International Energy Agency ◽  
Lessons Learned ◽  
Energy Agency ◽  
Net Zero ◽  
Successful Case ◽  
Sand Control ◽  
Zonal Isolation ◽  
The University ◽  
Gravel Pack

Our industry is under pressure to produce cleaner energy. That is the mantra, more so than a few years ago. A recent report from the International Energy Agency suggested that all greenfield developments in the oil and gas sector should be stopped forthwith if we are to achieve the net-zero target by 2050. That essentially means that we squeeze what we can from the not-so-easy and mature reservoirs, many of which have sand-control problems. Perhaps that is the reason most operators are working ever harder to manage and produce such assets, a trend reflected in the number of papers written. More importantly, a large proportion of papers this year were on sand consolidation and through-tubing exclusion methods, which primarily target mature producing reservoirs. A few technology trends are becoming apparent. There is a move to gravel pack longer and longer horizontal sections. It is now possible to pack more than 7,000 ft with zonal isolation. Through-tubing sand-control remediation continues to evolve. Sand consolidation is moving toward nanoparticles, with a promise of better regained permeability. Further strides have been made in developing filters to achieve behind-screen compliance for better sand retention. Industry has been enchanted by what data analytics and machine learning can potentially offer, and perhaps rightly so. Several papers this year apply these tools to sand management. For those interested, I would recommend paper SPE 200949 and OTC 31234 as further reading. Unfortunately, from a sand-control perspective, I do not yet see a compelling narrative. One interesting statistic that I stole from a LinkedIn post is that the rising 3-year trend of papers in OnePetro on this subject has fallen dramatically between 2020 and 2021. I have not independently verified these figures, but it does tell a story. Is the excitement waning? Recommended additional reading at OnePetro: www.onepetro.org. SPE 203238 - Sanding Propensity Prediction Technology and Methodology Comparison by Surej Kumar Subbiah, Universiti Teknologi Malaysia and Schlumberger, et al. SPE 201768 - Using Artificial Intelligence for Determining Threshold Sand Rates From Acoustic Monitors by Srinivas Swaroop Kolla, The University of Tulsa, et al. OTC 30386 - Pioneering Slickline Deployed Through Tubing Gravel Pack in Malaysia: Successful Case Study and Lessons Learned by Ertiawati Mappanyompa, Petronas, et al.

An efficient biotreatment process for polyvinyl alcohol containing textile wastewater

2013 ◽  
Vol 8 (3-4) ◽  
pp. 469-478 ◽  
Author(s):  
Sandip S. Magdum ◽  
Gauri P. Minde ◽  
Upendra S. Adhyapak ◽  
V. Kalyanraman
Keyword(s):  
Polyvinyl Alcohol ◽  
Process Optimization ◽  
Textile Wastewater ◽  
Cost Effective ◽  
Chemical Oxidation ◽  
High Rate ◽  
Microbial Consortia ◽  
Environment Friendly ◽  
Candida Sp ◽  
Textile Wastewater Treatment

The aim of this work was to optimize the biodegradation of polyvinyl alcohol (PVA) containing actual textile wastewater for a sustainable treatment solution. The isolated microbial consortia of effective PVA degrader namely Candida Sp. and Pseudomonas Sp., which were responsible for symbiotic degradation of chemical oxidation demand (COD) and PVA from desizing wastewater. In the process optimization, the maximum aeration was essential to achieve a high degradation rate, where as stirring enhances further degradation and foam control. Batch experiments concluded with the need of 16 lpm/l and 150 rpm of air and stirring speed respectively for high rate of COD and PVA degradation. Optimized process leads to 2 days of hydraulic retention time (HRT) with 85–90% PVA degradation. Continuous study also confirmed above treatment process optimization with 85.02% of COD and 90.3% of PVA degradation of effluent with 2 days HRT. This study gives environment friendly and cost effective solution for PVA containing textile wastewater treatment.

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