Redefining Fracpack For Sand And Fines Control Completion in 30 Years Old Producing Field

2021 ◽  
Author(s):  
Jagaan Selladurai ◽  
Cheol Hwan Roh ◽  
Amr Zeidan ◽  
Saurabh Anand ◽  
Bahrom Madon ◽  
...  
Keyword(s):  
Control Method ◽  
Movement Control ◽  
Work Flow ◽  
New Approach ◽  
Sand Control ◽  
Net Pressure ◽  
Ultimate Objective ◽  
Clastic Reservoirs ◽  
Gravel Pack

Abstract Malaysian clastic reservoirs are plagued with high fines content which rapidly deteriorates the productivity from wells completed with conventional form of sand control techniques. To mitigate the fines production issue, Petronas recently successfully completed 3 reservoirs in two wells in Field-D using enhanced gravel pack technique. This paper explains in detail the workflow, challenges such as depleted reservoirs, coal streaks, and nearby water contacts and operational execution for the successful re-defined extension pack jobs. This new approach consists of a re-defined Extension Pack / Frac Pack job with fine movement control resin and a re-defined perforation strategy. Perforation strategy consists of limited number of 180 deg phasing non-oriented perforations done under dynamic underbalance conditions. The key requirement to have fracturing as a sand control method is to have a tip screen out (TSO) or high net pressure placement to ensure the fracture has good conductivity. To obtain a good TSO, data acquisition is of paramount importance. The fracturing jobs in the Field – D wells were preceded with step-rate tests, injection tests, minifrac and Diagnostic Fracture Injection Test (DFIT). The data from diagnostic tests were used diligently to have best possible fracturing treatment in the target zones. Excellent pack factors of greater than 500 lbs. per ft were obtained for all the treatment jobs using only linear gel with proppant concentration up to 7 ppa. This high pack factor translates to very good frac conductivity which is essential in fracturing for sand control. Some of the fracturing treatments concluded with a TSO signature which is a big achievement considering the challenges that were associated with fracturing in Field – D. In addition, DFIT and ACA (After Closure Analysis) was performed to estimate permeability and results were compared with various techniques such as log derived and formation tester permeability. Ultimate objective from this analysis is to have a work-flow which can screen candidate wells for such treatments from openhole logs and give an estimated liquid rate post treatment. Also, the workflow for planning and executing fracturing jobs will be presented for Malaysian clastic reservoirs. This work-flow will be vetted against the extensive diagnostic and fracturing data that has been acquired during fracturing treatments in Field – D. Design, actual diagnostic, and fracturing data will be presented in this paper. It is expected that this modified form of sand and fines control will help in reducing the fines issue in Field – D to a great extent along with expected incremental in oil production. If long term production sustainability is proven, similar approach will be adopted by Petronas and can be shared amongst other South East Asia operators in many similar other fields.

Malaysia's First Successful Implementation of Sand Consolidation Technology as a Primary Sand Control Method Executed during the Drilling Phase: Success Story and Lessons Learned

2021 ◽  
Author(s):  
Nadiah Kamaruddin ◽  
Nurfuzaini A Karim ◽  
M Ariff Naufal Hasmin ◽  
Sunanda Magna Bela ◽  
Latief Riyanto ◽  
...  
Keyword(s):  
Control Method ◽  
Movement Control ◽  
Lessons Learned ◽  
Successful Implementation ◽  
Success Story ◽  
Control Solution ◽  
Consolidation Process ◽  
Execution Plan ◽  
Well Completion ◽  
Sand Control

Abstract Field A is a mature hydrocarbon-producing field located in eastern Malaysia that began producing in 1968. Comprised of multistacked reservoirs at heights ranging from 4,000 to 8,000 ft, they are predominantly unconsolidated, requiring sand exclusion from the start. Most wells in this field were completed using internal gravel packing (IGP) of the main reservoir, and particularly in shallower reservoirs. With these shallower reservoirs continuously targeted as good potential candidates, identifying a sustainable sand control solution is essential. Conventional sand control methods, namely IGP, are normally a primary choice for completion; however, this method can be costly, which requires justification during challenging economic times. To combat these challenges, a sand consolidation system using resin was selected as a primary completion method, opposed to a conventional IGP system. Chemical sand consolidation treatments provide in situ sand influx control by treating the incompetent formation around the wellbore itself. The initial plan was to perform sand consolidation followed by a screenless fracturing treatment; however, upon drilling the targeted zone and observing its proximity to a water zone, fracturing was stopped. With three of eight zones in this well requiring sand control, a pinpoint solution was delivered in stages by means of a pump through with a packer system [retrievable test treat squeeze (RTTS)] at the highest possible accuracy, thus ensuring treatment placement efficiency. The zones were also distanced from one another, requiring zonal isolation (i.e., mechanical isolation, such as bridge plugs, was not an option) as treatments were deployed. While there was a major challenge in terms of mobilization planning to complete this well during the peak of a movement control order (MCO) in Malaysia, optimal operations lead to a long-term sand control solution. Well unloading and test results upon well completion provided excellent results, highlighting good production rates with zero sand production. The groundwork processes of candidate identification down to the execution of sand consolidation and temporary isolation between zones are discussed. Technology is compared in terms of resin fluid system types. Laboratory testing on the core samples illustrates how the chemical consolidation process physically manifests. This is used to substantiate the field designs, execution plan, initial results, follow-up, lessons learned, and best practices used to maximize the life of a sand-free producer well. This success story illustrates potential opportunity in using sand consolidation as a primary method in the future.

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.

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.

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.

Reduction of major amputations in the diabetic ischaemic foot: A strategy to "take control" with conservative care as well as revascularisation

VASA ◽  
2001 ◽  
Vol 30 (Supplement 58) ◽  
pp. 6-14 ◽  
Author(s):  
Edmonds ◽  
Foster
Keyword(s):  
Natural History ◽  
Treatment Plan ◽  
Staging System ◽  
Vascular Control ◽  
New Approach ◽  
Conservative Care ◽  
Arterial Bypass ◽  
Therapeutic Footwear ◽  
Frequent Problem

The diabetic ischaemic foot has become an increasingly frequent problem over the last decade. However, we report a new approach consisting of a basic classification, a simple staging system of the natural history and a treatment plan for each stage, within a multi-disciplinary framework. This approach of "taking control" consists of two parts: 1. long-term conservative care including debridement of ulcers (to obtain wound control), eradication of sepsis (micribiological control), and provision of therapeutic footwear (mechanical control), and 2. revascularisation by angioplasty and arterial bypass (vascular control). This approach has led to a 50% reduction in the rate of major amputations in patients attending with ischaemic ulceration and absent foot pulses from 1989 to 1999 (from 4.6% to 2.3% per year). Patients who underwent angioplasty increased from 6% to 13%. Arterial bypass similarly increased from 3% to 7% of cases. However, even with an increased rate of revascularisation, 80% of patients responded to conservative care alone. This,we conclude, is an essential part of the management of all patients with ischaemic feet.

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.

Attention To Music In The Years Of Independence: A New Approach To Scientific Research

2020 ◽  
Vol 2 (09) ◽  
pp. 395-398
Author(s):  
Sultanov A. ◽  
Tajiboev E.
Keyword(s):  
Music Education ◽  
Education System ◽  
Scientific Research ◽  
Educational Technologies ◽  
New Approach ◽  
Modern Methods

This article reveals the attention paid to music education in Uzbekistan, the new approach implemented in the education system, the development of pedagogical educational technologies and modern methods based on long-term independence.

CHANGES IN BLOOD PROTEOME OF COSMONAUTS WITH MICRO- AND MACROVASCULAR INJURIES DUE TO G-LOADS AT THE FINAL STAGE OF LONG-DURATION SPACE MISSIONS

2020 ◽  
Vol 54 (5) ◽  
pp. 5-14
Author(s):  
L.Kh. Pastushkova ◽  
◽  
K.S. Kireev ◽  
I.M. Larina ◽  
◽  
...  
Keyword(s):  
Endothelial Cells ◽  
Soft Tissues ◽  
Blood Rheology ◽  
Landing Site ◽  
Space Missions ◽  
Vascular Injuries ◽  
New Approach ◽  
Long Duration ◽  
Integrated Response

The integrated response of the human proteome to re-entry g-loads following long-term space missions was studied in 13 male cosmonauts at the age of 44 ± 6 years. Examination at the landing site discovered local petechial hemorrhages into soft tissues of the back and lower legs. The paper presents a new approach to evaluation of petechia and soft tissue hemorrhages in cosmonauts on return to Earth. Proteomic analysis was performed with the use of LC-MS. Bioinformation analysis was made using Perseus, PubMed, Uniprot and ANDSystem software. Nine out of 19 significantly different (p < 0.05) proteins were related to vascular injuries directly. We described proteins with a primarily protecting effect against endothelial cells apoptosis and augmentation of vascular permeability, proteins that are responsible for blood rheology and proteins antagonistic to the main triggers of ischeamia-reperfusion injuries of the lungs, liver and other parenchymal organs.

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