Scale Inhibitor Squeeze Strategies in Horizontal Wells

Wesselingh, E.M.; Yuan, Shyan-Ming; Lemanczyk, R. Z.; Todd, Adrian Christopher

doi:10.2118/hwc-94-60

Cited by 4 publications

(4 citation statements)

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“…[1][2][3][4] However, the increasing use of horizontal and highly deviated wells in fields where scale formation is a potential problem has opened up a new area of research. 5,6 The large volumes of chemical which may be required to protect the producing intervals of these wells, combined with the difficulty of placing inhibitor where it is most effective, makes the need to model squeeze treatments more pressing than ever. In addition, further complications due to effects such as wellbore friction and crossflow may also be encountered.…”

Section: Introductionmentioning

confidence: 99%

“…The software that can perform these calculations must catch up with the requirements of modern well technology, and it is to address this issue that the ASSIST2 code has been developed. [5][6][7] A methodology for modeling such scale squeeze treatments using ASSIST2 has been reported previously. 6 The technique involves taking wellbore flow rates, derived from production logging data or calculated by a reservoir simulator, and using these to tune ASSIST2, which is a near-wellbore fluid flow and chemical transport simulator.…”

Section: Introductionmentioning

confidence: 99%

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Modeling Scale-Inhibitor Treatments in Horizontal Wells: Application to the Alba Field

Mackay

Matharu

Sorbie

et al. 2000

SPE Production &Amp; Facilities

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Many horizontal wells produce both oil and brine for an extended period of time and, therefore, in many cases the problem of mineral scale deposition must be solved. Scale management in long horizontal wells faces several challenges, a major one being the correct placement of the scale inhibitor slug in the formation. Accurate placement is required to ensure that vulnerable well sectors are treated, without wasting chemical in the protection of zones which will not cut water during the lifetime of the squeeze treatment.This paper presents results from a novel nearwellbore simulator ͑ASSIST2͒, which is used to model scale inhibitor treatments in horizontal wells. A technique for modeling such treatments has been developed which gives an improved understanding of where the chemical will be placed under different injection strategies, and how the placement will impact the squeeze life. It also allows the engineer to assess the impact of varying such parameters as inhibitor slug volume and concentration, overflush volume, injection rate, etc. Different inhibitor chemicals can be compared for their performance under the given reservoir conditions. This technique has been applied to model a squeeze treatment in a horizontal well where good production data are available. Connection oil and water flow rates, calculated by a full-field simulation model, have been matched by ASSIST2. Various treatment designs were tested to assess the impact of the controllable parameters listed above. Findings enabled a treatment to be specified that was predicted to increase the squeeze lifetime without increasing the volume of chemical required. This modeled application strategy will also reduce the initial inhibitor concentration spike in the return curve. The performance of various chemicals under reservoir flow conditions was modeled, with a clear best choice emerging from these studies.Based on the findings of this modeling work, recommendations were made for a squeeze treatment, which were implemented, and the resulting field data are presented.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Modeling Scale-Inhibitor Treatments in Horizontal Wells: Application to the Alba Field

Mackay

Matharu

Sorbie

et al. 2000

SPE Production &Amp; Facilities

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“…In addition, the increased capital investments and higher production rates associated with horizontal wells mean the risk of scale forming in the wellbore is even less tolerable than for conventional wells. For these two reasons, the existing models designed to calculate squeeze performance in vertical wells have been extended to simulate squeeze treatments in horizontal wells also (15)(16)(17) . Squeeze designs based on model findings have led to improved squeeze lifetimes and reduced process upsets during the early flow-back periods (18,19) .…”

Section: Introductionmentioning

confidence: 99%

Modelling Scale Inhibitor Squeeze Treatments in High Crossflow Horizontal Wells

Mackay¹

2000

Journal of Canadian Petroleum Technology

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Modeling scale inhibitor treatments in horizontal wells is emerging as an important field of research due to the need to reduce the cost of treating wells that may be thousands of feet long. Simulation studies performed using recently developed modeling tools have led to recommendations that have reduced the risk of chemical upsets at the wellhead and extended squeeze lifetimes downhole. However, as an increasing number of "problem wells," such as high crossflow wells, need to be treated to prevent scale formation, these models have to be adapted to enable them to capture the complex range of properties that make these systems so problematic. Diverter technology is being developed to enable optimal placement of chemical inhibitor, but to study the impact of the diverter on the squeeze performance, the fluid flow properties in the near-wellbore region must be modeled accurately. This is done by using a full-field reservoir simulation model that includes sufficient detail in the near-well formation not only to capture the fluid flows, but also to model accurately the chemical placement and recovery. The model can assess the impact of various placement strategies, as well as assist in determining the optimal fluid and chemical volumes. A case study from the North Sea where a gel diverter was selected to assist inhibitor placement is presented. The study demonstrates the types of calculation that can be made, and what information can be usefully supplied to the field engineer designing squeeze treatments. Introduction Mineral scale deposition in the near-wellbore area and tubular is a problem encountered in all types of production wells in the period following water breakthrough(1–3). Squeezing scale inhibitors into the near-wellbore formation is a strategy that has been used to successfully protect many hundreds of vertical wells(4–7). The squeeze treatment involves injection and over flush of a water-soluble chemical inhibitor that adsorbs onto the rock surface during a post-squeeze shut-in period. When the well is returned to production, the inhibitor slowly desorbs from the rock surface into the flowing water phase, and enters the well. Provided an appropriate choice of inhibitor is made, and provided it has been placed correctly, scaling tendencies in the produced water will be inhibited by the returning chemical for as long as its concentration remains above a threshold value(6,8). This Minimum Inhibitor Concentration (MIC) is routinely determined from laboratory Measurements(9). Modeling techniques have been developed to assist the design of squeeze treatments(10–14). Use of these models for optimizing treatments in vertical wells has proved very successful, and simulations are often performed as a matter of routine when designing treatments. However, the long production intervals associated with horizontal and deviated wells, along with the possibility of extended production at high water cuts, can make the design of squeeze treatments in these wells much more difficult. In addition, the increased capital investments and higher production rates associated with horizontal wells mean the risk of scale forming in the wellbore is even less tolerable than for conventional wells.

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“…For these two reasons, the existing models designed to calculate squeeze performance in vertical wells have been extended to simulate squeeze treatments in horizontal wells also. [15][16][17] Squeeze designs based on model findings have led to improved squeeze lifetimes and reduced process upsets during the early flow-back periods. 18,19 This kind of calculation has typically been performed using near-wellbore models.…”

Section: Introductionmentioning

confidence: 99%

Modelling Scale Inhibitor Squeeze Treatments in High Crossflow Horizontal Wells

Mackay¹,

Sorbie²

1998

Proceedings of SPE International Conference on Horizontal Well Technology

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractModelling scale inhibitor treatments in horizontal wells is emerging as an important field of research due to the need to reduce the cost of treating wells that may be thousands of feet long. Simulation studies performed using recently developed modelling tools have led to recommendations that have reduced the risk of chemical upsets at the wellhead and extended squeeze lifetimes downhole.However, as an increasing number of "problem wells," such as high crossflow wells, need be treated to prevent scale formation, these models have to be adapted to enable them to capture the complex range of properties that make these systems so problematic.Diverter technology is being developed to enable optimal placement of chemical inhibitor, but to study the impact of the diverter on the squeeze performance, the fluid flow properties in the near-wellbore region must be modelled accurately. This is done by using a full-field reservoir simulation model that includes sufficient detail in the near-well formation not only to capture the fluid flows, but also to model accurately the chemical placement and recovery. The model can assess the impact of various placement strategies, as well as assist in determining the optimal fluid and chemical volumes.A case study from the North Sea where a gel diverter was selected to assist inhibitor placement is presented. The study demonstrates the types of calculation that can be made, and what information can be usefully supplied to the field engineer designing squeeze treatments.

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Scale Inhibitor Squeeze Strategies in Horizontal Wells

Cited by 4 publications

References 0 publications

Modeling Scale-Inhibitor Treatments in Horizontal Wells: Application to the Alba Field

Modeling Scale-Inhibitor Treatments in Horizontal Wells: Application to the Alba Field

Modelling Scale Inhibitor Squeeze Treatments in High Crossflow Horizontal Wells

Modelling Scale Inhibitor Squeeze Treatments in High Crossflow Horizontal Wells

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