Squeezing the Bakken: Successful Scale Squeeze Programs Lead to Shift in Bakken Scale Control

Spicka, Kevin; Eagle, Lisa Holding; Littlehales, Ian; Fidoe, Julie; Jordan, Myles Martin; Zosel, Z..; Glasser, Saralee

doi:10.2118/184565-ms

SPE International Conference on Oilfield Chemistry 2017

DOI: 10.2118/184565-ms

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Squeezing the Bakken: Successful Scale Squeeze Programs Lead to Shift in Bakken Scale Control

Kevin Spicka

Lisa Holding Eagle

Ian Littlehales

et al.

Abstract: This paper highlights efforts taken in answering the following question: "Can horizontal unconventional shale wells be successfully squeezed for scale control?". The Bakken shale formations in North Dakota, Montana and Alberta have presented unique operational challenges during the unconventional play boom. Despite the ability to control scale formation with conventional scale inhibitors under Bakken conditions, scale formation (primarily calcium carbonate) can still remain an operational challe… Show more

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Cited by 6 publications

References 17 publications

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Simulation Study for Scale Management During Shale Gas Production

Xu¹,

Mackay²

2018

Day 2 Thu, June 21, 2018

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Hydraulic fracturing for shale gas production involves pumping large volumes of water; as a consequence of this, produced water management is an important topic to address in order to sustainably produce shale gas. It has been well documented that only approximately 10-40% of the pumped fluids will be produced back to the surface, and that there will be increased concentrations of various ions in the flowback water during this process. This flowback water, with high total dissolved solids and high concentrations of certain ions, presents a significant risk of mineral scaling (Blauch, 2009). In general, it can be very challenging to identify the in situ formation water composition in shale reservoirs since samples of the formation water can be difficult to obtain. They may have been contaminated during the drilling process, reactions may have taken place due to fluid mixing between the injected fluid and the formation water, or simply they may not have been preserved appropriately (Pan, 2017). Some calculations of formation water compositions require to be preceded based on the observed compositional data; thereafter, the predicted formation water compositions are validated by comparison with the observed total dissolved solids (TDS) data. A two-phase 3D numerical flow model has been developed that includes a hydraulic fracture and is populated with shale reservoir properties. (This model assumes the hydraulic fracture is already established – i.e. the calculations include coupled flow and component transport, but the geomechanics are not considered). It is used to simulate fluid transport mechanisms within the shale system and to address the question – what causes the significant retention of fracture fluid in shale reservoirs. A series of simulations was performed to achieve a history match with observed flowback water data in a western Canadian basin (the Horn River Basin). A further two-phase 3D flow model was developed to examine the scaling tendency due to the evolving produced brine composition over the lifetime of the well. It is based on the previously history matched model and includes the fracture fluid and formation water compositions to predict precipitation of minerals. Finally, scale inhibitor injection was simulated to examine the impact of inhibitor retention on well protection.

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Simulation Study for Scale Management During Shale Gas Production

Xu¹,

Mackay²

2018

Day 2 Thu, June 21, 2018

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Unconventional Horizontal Scale Squeezes: Lessons Learned Drive Continued Development and Improved Cost Savings

Eagle

Spicka

Fidoe

et al. 2018

Day 1 Wed, June 20, 2018

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It has been proven that scale squeezes can be conducted effectively in the unconventional, horizontal fractured wells in the shale reservoir of the Bakken when using an optimal scale squeeze chemistry. Previous work has discussed inhibitor selection and performance testing along with early case histories and modeling work. This paper discusses new case histories and Place-iT modeling results based on several procedural variations including a range of overflush volumes in the squeeze treatment procedure and the inclusion of acid cleanouts. Novel, reduced-volume squeeze designs have successfully protected wells from scale deposition while limiting the direct and indirect costs associated with extra placement water. For unconventional shale wells in the Bakken, where produced water is typically very high in TDS and TSS, fresh water is most commonly used to execute squeezes. Reducing the total water volume reduces the costs of purchasing, transporting and storing fresh water. The amount of time and cost to pump the job is decreased. Less time and money is spent lifting the placement water, and consequently, there is less deferred production. In addition, in unconventional production acid treatments are commonly carried out in isolation to maintain production. In this work, applying acidizing stages at the front of the squeeze procedures, provides a novel "squimulation" process to fractured reservoir scale control treatments. For these unconventional horizontal wells, the use of larger water volumes—either several times full wellbore volume and/or several times daily water production—has not been shown to improve the longevity or cost-effectiveness of squeeze jobs. Contrary to conventional well applications modeled with Darcy flow, it appears diffusion is the more applicable mechanism for scale inhibitor transport in fractured shale wells. This mechanism is consistent with a reduced dependence on water volume deployed in the treatments. The lessons learned from the unconventional horizontal scale squeezes conducted in the Bakken have resulted in enhanced production and cost savings. There are significant implications for the industry as other key unconventional regions in the U.S. and around the world are looking into scale squeezes as an option for scale control.

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The Biggest Elephant in the Room in Unconventional Scale Programs: Iron

Spicka¹,

Bhandari²,

Bhandari³

et al. 2020

Day 2 Thu, June 25, 2020

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The development of unconventional basins across North America for the past decade initially caused some in the industry to wonder if challenges found in unconventional basins would require new chemistries and technologies. As the basins have been produced and water chemistries evaluated and treated, it has become clear that established scale inhibitor chemistries and methodologies are suitable to treat unconventional scaling scenarios. However, the number of applicable chemistries can be limited as some of the most common scale inhibitor chemistries have been found lacking in iron tolerance. The biggest lesson learned over the course of the past decade has been to not underestimate the role that iron can play as spoiler not only in performance of scale inhibitor chemistries, but also in test methodologies and monitoring techniques. While the need to account for iron in conventional programs has not been taken for granted, the amount of iron produced in unconventional production basins has led to a re-evaluation of just how severely iron in solution can impact scale programs from product testing and selection all the way through to program monitoring. This paper highlights the brine chemistries in major North American unconventional basins, especially regarding iron. Test methods and results from dynamic scale loop and anaerobic static bottle testing will be highlighted as well as the limitations of using field brines in product evaluations. Field observations will be discussed to support the importance of proper product selection as well as monitoring techniques. This subject has implications for the industry as unconventional basins across North America continue to search for program improvements to drive reductions in total operational costs. Additionally, as unconventional basins are developed outside of North America, the lessons learned can be applied to efficiently develop best in class scale inhibitor programs. As appreciation for the impact of high levels of iron on scale inhibitor performance continues to evolve, there is a possibility that a smaller amount of iron tolerant scale inhibitors will limit the treatment options available in unconventional production basins.

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Squeezing the Bakken: Successful Scale Squeeze Programs Lead to Shift in Bakken Scale Control

Cited by 6 publications

References 17 publications

Simulation Study for Scale Management During Shale Gas Production

Simulation Study for Scale Management During Shale Gas Production

Unconventional Horizontal Scale Squeezes: Lessons Learned Drive Continued Development and Improved Cost Savings

The Biggest Elephant in the Room in Unconventional Scale Programs: Iron

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