Acidizing: A Small Change in Recipe, A Big Improvement in Production.

Wahib, Suhaila; Effendi, Shahrul Nizam Mohd; Choo, Der Jiun; Seng, Wong Chun; Ramnarine, Ronald Peter

doi:10.2118/132766-ms

Cited by 3 publications

(1 citation statement)

References 2 publications

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“…Generally, solid-phase invasion, fines migration, scale formation, and water sensitivity (Chen and Dai 2005;Wu et al 2007;Buchsteiner 1993;Sadeghazad and Beiranvand 2003) can cause pollution and plugging near the wellbore which has adverse effects on oil production. Acidizing treatment is one of the most important techniques that has been utilized in attempting to remove the pollution and recover formation permeability (King 1986;Wahib et al 2010;Buijse et al 2004;Pournik et al 2011). Acidizing treatment involves an injection of acidizing solution, such as HF, HCl, or HBF 4 into the formation which can react with clay particles, carbonate, and FeS, and thus, the permeability near the wellbore is recovered.…”

Section: Introductionmentioning

confidence: 99%

Research on a temporary plugging agent based on polymer gel for reservoir acidification

Zhao

Dai

et al. 2015

J Petrol Explor Prod Technol

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A temporary plugging agent based on polymer gel was successfully prepared for temporary plugging in acidizing treatment. The gelation time, gel-breaking time, viscosity changes, temporary plugging capacity, and permeability recovery capacity were investigated. Increasing the polymer and cross-linker concentration reduced the gelation time of the polymer gel and temporary plugging agent, but caused difficulties in breaking the temporary plugging agent. Ammonium persulfate (APS) could be the driving force for the differences of gelation time between the polymer gel and temporary plugging agent. Additionally, increasing APS concentration made the temporary plugging agent break easily. Viscosity changes are the most important feature of a temporary plugging agent. According to the viscosity changes, the whole process can be divided into two major stages: the cross-linking reaction stage and the degradation reaction stage. The temporary plugging agent had a good plugging capacity which could effectively plug the high permeability zones. By temporary plugging, the pollution near wellbore was removed without damaging non-target zones. As a result, the permeability of the low permeability zones was greatly improved, and the permeability of the high permeability zones was effectively recovered.

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Section: Introductionmentioning

confidence: 99%

Research on a temporary plugging agent based on polymer gel for reservoir acidification

Zhao

Dai

et al. 2015

J Petrol Explor Prod Technol

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Investigating the effects of polymer plugging mechanism of liquid production decrease and improvement by the cross-linked gel performance

Ma¹,

Zene

et al. 2021

Sci Rep

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Polymer flooding, as the most successful and well-known chemical EOR method was broadly applied around the world. Mostly, contrasted with Waterflooding, the production rate decrease during polymer flooding is smaller based on field application. Nevertheless, the production liquid rate decreased critically in the middle phase to late phase due to plugging, which could lead the way to poor flooding performance and fewer cumulative oil. In this work, first, we approached the affecting polymer plugging mechanism model on liquid production decrease to investigate the parameters such as; solid-phase concentration (SOLIDMIN), reacting frequency factor (FREQFAC) and others affecting components are all investigated consecutively. Secondly the model approached by cross-linked gel for the improvement of production liquid rate. The physical work was designed by a physical model, and then the polymer adsorption that generating blockage emerging in permeability diminish assessed by a mathematical model. The outcomes specify that the existence of this debris, excessive assemblage of solid-phase and the excessive reactant frequency factor has major mechanical and physical parameters effects on the reservoir throughout polymer flooding. Polymer flood model base case liquid ratio loss is 11.15 m3/day between the years 2014-08-01 to 2020-03-04. Comparing with the polymer flood model case 1, liquid ratio loss ranging to 1.97 m3/day between the years 2014-08-02 to 2020-03-03. While the oil ratio loss of the polymer flood base case model between the years 2015-07-08 to 2020-03-04 attained 12.4 m3/day contrasting with the polymer flood model case 1 oil ratio increase to 0.37 m3/day between the years 2014-08-04 to 2019-04-02. The cross-linked gel model base case liquid ratio loss is 2.09 m3/day between the years 2015-01-02 to 2020-02-03, while the oil ratio lost reached 9.15 m3/day between the years 2015-09-01 to 2020-02-03. Contrasting with the cross-linked gel model case 2 liquid ratio recovered from the loss and attained 25.43 m3/day in the year 2020-12-01, while the oil ratio is reached 15.22 m3/day in the year 2020-12-01. Polymer flood model examined through cross-linked gel model performed reliable outcomes by taking out the plugging, which also occasioned the reservoir production rate to decrease. With the application of cross-linked gel the affected parameters and the production rate have achieved an improvement.

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Key Parameter of Successful Matrix Acidizing to Combat Fines Migration in Gravel Pack Wells

Primasari

Abidiy

Ismail

et al. 2020

SPE/IATMI Asia Pacific Oil &Amp; Gas Conference and Exhibition

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In common practice, gravel pack completion is beneficial as sand control in a typical unconsolidated sandstone reservoir. However, with poorly sorted sand grains, fines migrate and deposit at the gravel-pack matrix, causing permeability reduction and hence, decreasing well productivity. Matrix stimulation has been proven to remove the fines blocking the pore throat. The desired solution has been carefully selected to have prolonged well production. Organic clay acid is chosen for to its ability to have deeper penetration and to create a thin coating on the pore surface to prevent fines migration. Laboratory testing and field application were performed in parallel. A core flood test with reservoir core samples showed a result of 111% regained permeability. Ten treatments were conducted and showed good results. The productivity index increases 10 times on average. From those experiences, a benchmark was identified, which factor determines the success of a treatment. This paper presents the project preparation and execution, key reasons to success, and the way forward.

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Acidizing: A Small Change in Recipe, A Big Improvement in Production.

Cited by 3 publications

References 2 publications

Research on a temporary plugging agent based on polymer gel for reservoir acidification

Research on a temporary plugging agent based on polymer gel for reservoir acidification

Investigating the effects of polymer plugging mechanism of liquid production decrease and improvement by the cross-linked gel performance

Key Parameter of Successful Matrix Acidizing to Combat Fines Migration in Gravel Pack Wells

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