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

Kamaruddin, Nadiah; Karim, Nurfuzaini A; Hasmin, M Ariff Naufal; Bela, Sunanda Magna; Riyanto, Latief; Samuel, Orient Balbir; Jeffry, Suzanna Juyanty Mohd; Hashim, Saharul; Balasandran, Anandhadhasan; Ramírez, Cristián; Mohan, Ragupathy

doi:10.2118/205686-ms

Cited by 3 publications

(1 citation statement)

References 4 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Geological factors refer to the geological conditions in which the well is located, including the geological age of the area around the hole, particle uniformity, cementation and degree of cementation (Table 1) (Ubuara, et al, 2024;Balasandran A et al, 2021). The reasons for sand production in oil wells are not always the same, and there may be some differences in the causes of sand production among oil wells in different regions, One of the main aspects is the geological conditions of the reservoir itself, which mainly include the following aspects (Madasu and Vo., 2016;Hassan N A et al, 2020;Kueh J Z et al, 2022;Mahardhini A et al, 2021).…”

Section: Geological Factorsmentioning

confidence: 99%

A critical review on analysis of sand producing and sand-control technologies for oil well in oilfields

He,

Pang,

Ren

et al. 2024

Front. Energy Res.

View full text Add to dashboard Cite

Sand production in oil wells seriously affects the production of oil and gas in oilfields. Although conventional sand-control techniques can effectively prevent sand production, it may also limit the productivity of oil wells. Fracturing and packing sand control technology changes the distribution of pressure and flow in the wellbore, while foam polymer resin diversion technology reduces the anisotropy of reservoir permeability and increases the area of oil leakage in the reservoir, both achieving the goal of sand control and increased production. The sand-free production rate is successfully increased thanks to zeta potential sand control technology, which modifies the formation’s sand potential and causes the sand to agglomerate without harming the reservoir. This article first looks into the causes of sand production in oil and gas wells before examining the fundamentals, implementation strategies, and effects of traditional sand control techniques, fracturing and filling sand control technology, foam polymer resin diversion technology, and Zeta potential sand control technology. In this article, the experience of sand control technology in actual oil field applications is summarized, explained in detail, and the future development possibilities of sand control technology are discussed.

show abstract

Section: Geological Factorsmentioning

confidence: 99%

A critical review on analysis of sand producing and sand-control technologies for oil well in oilfields

He,

Pang,

Ren

et al. 2024

Front. Energy Res.

View full text Add to dashboard Cite

show abstract

Application of Resin Sand Consolidation as Primary Sand Control: Case Study of a New Development Well in Offshore Sarawak

Hasmin

Jeffry

Tusimin

et al. 2022

Day 2 Tue, November 01, 2022

View full text Add to dashboard Cite

Various sand control completion techniques have been applied to address sand production issues in Field A. The sand production challenges are often aggravated with decreasing reservoir pressure and increasing water cut due to fields maturity. Conventional gravel pack methods such as circulation pack or high-rate water pack were effective and has high reliability in controlling sand production. However, these methods often resulted in high initial skin (subjected to gravel sizing, completion fluids, screen sizing, etc.) which affect the well productivity. For wells with fines migration issues, the skin will further build-up as the well produce over time. In addition, these sand control methods are associated with higher installation cost. In order to address these issues, Resin Sand Consolidation technique was successfully applied as primary sand control in Well 8 to prove its reliability, productivity, and cost effectiveness. It was the first application for a new development well in Field A and second in PETRONAS Carigali Sdn. Bhd. (PCSB) Malaysia fields (first implementation in 1998). This paper explains the detailed workflow from candidate selection to execution, challenges, and results from this successful pilot. There were three reservoirs completed in Well 8. The perforation strategy utilized 4 SPF 10/350 degree phasing self-gravitated oriented perforations which was executed under dynamic underbalance conditions to achieve optimal perforation tunnel cleanup. The perforation interval was kept short (< 10 ft) to ensure uniform treatment. One of the key steps in achieving successful resin placement is formation injectivity. Acid was pumped and injectivity tests were conducted before and after pumping to assess the effectiveness of acid treatment. The data acquired from the step rate test was used to determine the Fracture Closure Pressure (FCP) and Fracture Extension Pressure (FEP) where it will define the maximum pumping rate during the sand consolidation treatment. Identification of maximum pumping rate is crucial to ensure optimum displacement of resin into the formation during execution. Pre-acid injectivity results showed poor injectivity in all 3 reservoirs with treating pressures recorded more than the MASTP limit to reach pumping rate of 2 bpm. Near well bore damage removal treatments were executed using mud acid (15% HCl + 1.5% HF) followed by post-injectivity test which showed improvement in treating pressures. By the end of the operation, a total of 68 bbls of treatment fluid was successfully pumped into all three reservoirs. Well tests acquired during unloading and production phase have shown good results exceeding the target rate set during FDP with no sand production observed. It is expected that this new way of sand control for new wells could contribute towards reducing sand production issues in Field A while at the same time provide an incremental gain in oil production. The success of this pilot would open-up more opportunities in PCSB and other operators towards the implementation of similar sand control method for new development wells.

show abstract

Sand Consolidation Treatment: Durability in an Alternative Primary Sand Control Method for a Marginal Reservoir

Kueh

Tan

Dev

et al. 2022

Day 2 Tue, February 22, 2022

View full text Add to dashboard Cite

Field A is mature hydrocarbon producing field located in east Malaysia discovered in 1963. With multistacked reservoirs more than 7,000 ft high, the reservoirs are predominantly friable and unconsolidated, requiring sand exclusion from the beginning. Most of the wells were completed using internal gravel pack (IGP) methods in the main reservoir. Being an aging producing field, many of the main reservoirs have been depleted and watered out, making the wells inactive. There are, however, several shallower marginal reservoirs, which have been bypassed and undeveloped, known as behind casing opportunity (BCO) reservoirs. The challenge is accessibility to this sand prone reservoir, which might require substantial workover operations, and thus higher costs. Remedial options with proven screen completion can be costly and economically difficult to justify. Mid-2020 marks seven and a half years since the application of a single treatment of epoxy resin in an idle well located in Field A as a remedial approach for BCO. The treatment, proven economically attractive by yielding cost savings of USD 5 million compared to the workover option, further supported by rigorous production monitoring, is unequivocally valuable based on the duration of sustained sand-free production, once again providing reassurance in making this solution a reliable sand-control remedial method for marginal reservoirs. It is important to note that the solution considered a range of laboratory data associated with the chemicals that effectively addressed the requirement based on the characteristics typical of this formation. Well test data from 2013 to 2019 supported sand-free production. Despite experiencing an increment of water cut percentages up to 93.29%, the well is still performing at acceptable production rates. The groundwork processes of candidate identification to the execution of converting the well are described, emphasizing technology comparisons applied in terms of resin fluid system type, execution plan, lessons learned, and best practices developed for maximizing the life of a sand-free producer well.

show abstract

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

Cited by 3 publications

References 4 publications

A critical review on analysis of sand producing and sand-control technologies for oil well in oilfields

A critical review on analysis of sand producing and sand-control technologies for oil well in oilfields

Application of Resin Sand Consolidation as Primary Sand Control: Case Study of a New Development Well in Offshore Sarawak

Sand Consolidation Treatment: Durability in an Alternative Primary Sand Control Method for a Marginal Reservoir

Contact Info

Product

Resources

About