Scale Mitigation Enhances Safety and Production

Lewis, D.R.; Zainalabedin, K.A.; Al-Habib, N.S.; Al-Beaiji, T.M.; Al-Qahtani, A.M.; Nasr-El-Din, H.A.

doi:10.2523/81569-ms

Cited by 3 publications

(3 citation statements)

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“…The following key performance criteria were considered when selecting the optimum scale inhibitor: (1) No change in the appearance or the rheology of the acid system, (2) Minimal precipitation upon mixing with the acid or materials present in the wellbore, typically ferric iron or calcite scale, (3) No effect on the reaction kinetics or corrosivity of the acid solutions, and (4) Minimal loss in the performance of the inhibitor itself when mixed in the acid.…”

Section: Screening Various Inhibitorsmentioning

confidence: 99%

“…This type of scale forms in three oil fields in Saudi Arabia: two carbonate reservoirs, and a sandstone reservoir. Calcium carbonate scale forms in the top 1,000 ft of the two carbonate reservoirs (B and G), [2][3][4] while forming downhole in the sandstone reservoir (H). [5][6][7] CaCO 3 scale formation in the producing wells can be represented by Equation 1.…”

Section: Introductionmentioning

confidence: 99%

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A Single-Stage Acid Treatment to Remove and Mitigate Calcium Carbonate Scale in Sandstone and Carbonate Reservoirs

Nasr-El-Din¹,

Al-Saiari²,

Al-Hajji³

et al. 2004

Proceedings of SPE International Symposium on Oilfield Scale

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Combining scale inhibition with matrix stimulation in a single treatment has always been a challenge due to potential formation damage. This concern has been historically prominent in carbonate reservoirs, due to the accelerated precipitation of the scale inhibitor at very low pH values. Earlier experience in combining acid stimulation with scale inhibition in carbonate reservoirs has been reported with limited success.This paper presents recent development in combining acid stimulation and scale inhibition treatments in sandstone and carbonate reservoirs. The combined treatment utilizes a newly developed scale inhibitor (a polymer-based inhibitor) that offers full compatibility with a wide range of the commercially available acidizing systems, including hydrochloric acid, mud acids and chelating agents.This treatment minimizes the number of well interventions, significantly reduces well maintenance cost and improves the work-over efficiency. At least one scale inhibitor squeeze treatment is eliminated with every acid stimulation treatment. In addition, there are other inherent advantages including: effective inhibitor placement and better coverage of the target zone.

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Section: Screening Various Inhibitorsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

A Single-Stage Acid Treatment to Remove and Mitigate Calcium Carbonate Scale in Sandstone and Carbonate Reservoirs

Nasr-El-Din¹,

Al-Saiari²,

Al-Hajji³

et al. 2004

Proceedings of SPE International Symposium on Oilfield Scale

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show abstract

“…The scaling problems occur during pressure decrease of the produced formation water. The effect may be reduced performance of the well and in some cases influence on the operation of downhole safety valves 1 . The carbonates precipitate from the produced water as release of CO 2 gas gives increased pH and supersaturation of CaCO 3 .…”

Section: Introductionmentioning

confidence: 99%

Predicting Carbonate Scale in Oil Producers from High Temperature Reservoirs

et al. 2004

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractCalcium carbonate scale is a common problem in the oil industry leading to reduced well performance and obstruction of the safety valves. Recent field experiences indicate that scaling may be a problem at lower Saturation Ratio (SR) than earlier anticipated. In a high pressure, high temperature Scale Cell crystal growth in synthetic formation water has been studied. Induction times and growth rates have been determined using a microscope cell. The results have been interpreted using nucleation theory. The findings indicate that wells may be safely operated at SR below 2.5 at 85 o C. At higher temperature crystal growth is less dependant on SR and the temperature dominates the system. Care should therefore be taken when operating wells at temperature above 100 o C.

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Holistic Management of Calcium Carbonate Scaling in a Mature Field: A Case Study

Pant

Tiwari

Fartiyal

et al. 2017

Day 3 Wed, April 26, 2017

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Calcium carbonate scaling within well tubing and surface piping leads to significant production loss in many oilfields across the world. Scaling tendency of produced fluids increases multi-fold in a mature reservoir with increase in water production and decline in operating pressures. This paper demonstrates the use of modelling to help anticipate scaling issues and convert predictions into operational decisionmaking which has prevented significant value erosion in a mature field. Majority of the efforts in tackling scaling related losses have traditionally been centered on performing scale treatment after observing a significant change in flow parameters. Although this approach delivers value, it is more reactive in nature and becomes challenging to address in a logistically constrained offshore environment. This paper presents a case study on a new proactive framework on Scale Management. This new framework is driven by P2P approach - Prediction to Prevention. Prediction of scale formation tendency in wells was carried out using a thermodynamic model. Once wells with scale formation tendency were identified using thermodynamic model, scale prevention was done by selection and application of scale inhibitor chemical along with progressively reducing number of surgical acid washes. The scaling behavior was compared against the operating conditions of wells and the findings complemented the understanding from thermodynamic simulations. Paper deliberates on the cost optimization while application of this approach so that it remains extremely cost efficient in comparison to traditional approach. It details the evolution of scale management strategy right from project initiation to field maturation spanning across 30 years of production. With periodic reviews of this framework, additional ~10% of available well stock was identified as new wells migrating into scaling envelope over the last one year and added to Scale Inhibitor dosage program. This prevented production losses and well integrity issues in these wells. Wells put on continuous scale inhibitor injection as per recommendations of this approach did not have down-hole safety valve failures, protecting 35% of field oil production volume and ensuring safer operations demonstrating strong business value. Overall, application of this P2P framework has helped asset to reduce yearly scaling related losses by more than 90%.

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Scale Mitigation Enhances Safety and Production

Cited by 3 publications

References 0 publications

A Single-Stage Acid Treatment to Remove and Mitigate Calcium Carbonate Scale in Sandstone and Carbonate Reservoirs

A Single-Stage Acid Treatment to Remove and Mitigate Calcium Carbonate Scale in Sandstone and Carbonate Reservoirs

Predicting Carbonate Scale in Oil Producers from High Temperature Reservoirs

Holistic Management of Calcium Carbonate Scaling in a Mature Field: A Case Study

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