North Sabah EOR ADP – Examining the Challenges of Offshore ASP Development

Kovalev, K.; Agarwal, Binayak; Harris, R. R.; Jaspers, Henri F.

doi:10.2118/179852-ms

Day 3 Wed, March 23, 2016 2016

DOI: 10.2118/179852-ms

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North Sabah EOR ADP – Examining the Challenges of Offshore ASP Development

K. Kovalev

Binayak Agarwal

R. R. Harris

et al.

Abstract: Three producing fields, located offshore Sabah in northern Borneo are currently being jointly considered Enhanced Oil Recovery (EOR). An initial screening study conducted in 2009/2010, indicated that a successful implementation of Alkali Surfactant Polymer (ASP) flooding might result in significant improvement in the ultimate recovery from the field. Due to a limited experience with ASP flooding in offshore environment, a joint Shell and PETRONAS Carigali team was tasked to explore the entire so… Show more

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Cited by 4 publications

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“…emulsion handling and disposal, including back produced chemicals on the facilities, (5) chemical discharge associated to produced water, (6) high adsorption of chemicals, (6) localized heterogeneities affecting the objective observation of the results, (7) unconstrained fracture growth on the rock (more viscous fluid injected) and (8) measuring the saturation of oil accurately on the observation well during the pilot phase.A joint Shell and PETRONAS evaluation of the technical challenges of implementing an ASP flooding in three offshore producing fields in northern Borneo with a focus on space solution(KOVALEV et al, 2016). For it, four anchor cases were detailed and analyzed: (1) high injection, (2) medium injection, (3) low injection, and (4) only polymer.…”

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confidence: 99%

Optimization and comparison between polymer, surfactant-polymer and water flooding recoveries in a pre-salt carbonate reservoir considering uncertainties.

García¹,

Sebastian²

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A successful Chemical Enhanced Oil Recovery (CEOR) program starts with a proper process selection for a given field, followed by a formulation of the batch components and a representative simulation step. Also, lab studies, field data, pilot testing, and economic analyses are required before project implementation. This work discusses the state of the art of the Surfactant-Polymer flood (SP) EOR technique, specifically for carbonate reservoirs, and states a methodology mixing laboratory, literature and reservoir simulation, to assess its applicability under economic and geological uncertainties. First, it is explained concepts related to the research, such as polymer, surfactant, microemulsion, functionalities of each chemical injected, advantages, and disadvantages. Second, a state of the art is developed about recent SP advances. Third, it is described the laboratory method being used to evaluate some properties of the chemicals injected for the Polymer flooding (PF) and SP flooding. Later, the simulation study step being conducted is explained, which will define the volume recovered and Net Present Value (NVP) obtained for the PF, SP injections and water flooding, in different economic and geological scenarios for two models resembling carbonate Brazilian reservoirs. Finally, it is discussed the results obtained, future researches that could be performed, and the respective bibliography. As part of this research, it was verified the Xanthan gum shows adequate results at different concentrations; that a surfactant specifically selected for a carbonate rock with low Interfacial tension and low adsorption is required; also that for the Lula based model although the polymer flooding and Surfactant-Polymer simulation brought some benefits, when compared with the waterflooding, on different economic scenarios and geological models, the high cost associated to the chemical handling facilities and volume spent do not make favorable its application in any scenario. On the contrary for the Cerena I field model, it was found the SP and Polymer flooding on all cases brought better results when compared with the water injection. Concluding that the performance and success of a CEOR program require finding the correct slug characteristics for the unique conditions of each reservoir. In this research the reservoir with higher production rates made possible the use of Chemical EOR presenting better results than a water injection however in the smaller model they were not economically viable due to the additional associated prices.

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confidence: 99%

Optimization and comparison between polymer, surfactant-polymer and water flooding recoveries in a pre-salt carbonate reservoir considering uncertainties.

García¹,

Sebastian²

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Evaluation of Seawater Based Surfactant Polymer Formulation in a Single Well Test Offshore

Harris

Paramanathan

Dickson

et al. 2020

Day 2 Tue, September 01, 2020

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The effectiveness of a low complexity chemical flooding formulation that was developed for application in offshore environments was evaluated in a single well test offshore South China Sea. The SP formulation uses seawater with no additional water treatment beyond that which is normally performed for water flooding (filtration, de-oxygenation, etc.). The ability to use a formulation based on only seawater avoids water treatment and reduces complexity for commercial implementation. The Single Well Test was conducted in an existing producer with its wellhead on an existing production platform offshore. The injection facilities were placed on work barge that also had accommodation to house the people that executed the injection test. The facilities on the barge consisted of seawater lift and filtering equipment, surfactant and polymer mixing capability, and high-pressure pumps to deliver the mixed fluids through a flexible high-pressure hose to the platform. A laboratory to support the QA/QC of the injected fluids was also installed on the barge. Standard Single Well Chemical Tracer test procedures were applied to determine the remaining oil saturation after waterflood and after injection of the SP formulation. The Single Well Test was completed in accordance with the objective without any recordable HSSE cases ahead of schedule. The composition of the injected SP formulation was well within the specifications resulting in good injectivity of the formulation. The single well tracer tests conducted after the SP and polymer injection indicate that the residual oil saturation was reduced to values between 7-9% (Sorc). The main contributions described in the paper are: demonstration that a seawater-based SP formulation can be effectively mixed and injected from a barge offshore. the interpretation of the single well tracer tests conducted after the SP and polymer injection indicate that the residual oil saturation was reduced to values similar to those observed in core floods with the SP formulation in the laboratory.

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Surfactant Polymer SP vs. Alkali-Surfactant Polymer ASP: Do We Need the a in ASP?

Delamaide¹,

Rousseau

Wartenberg

2021

Day 3 Tue, November 30, 2021

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The first surfactant-based pilots can be traced back to the 1960s and since then almost a hundred field tests have taken place. Interestingly, almost half of these pilots have used an alkali (ASP) and the other half has not (SP). This reflects the current status of the industry which is divided along the same lines and over the same question: do surfactant-based processes require alkali or not? This paper proposes to address this question by providing explanations and discussing case studies. The paper will start by reminding the reader of the role of both surfactant and alkali and will review the pros and cons of alkali in terms of formulation performances, adsorption but also surface facilities and logistics. Several cases studies (lab and field) will be discussed to show when alkali can and cannot be used, and what solutions are available as alternatives to the use of alkali. Although alkali allows reducing both surfactant concentration and adsorption, it can also cause severe scaling and requires additional facilities including water softening; in addition, the large volumes of alkali required can cause logistical challenges. On the other hand, the main challenges of formulations without alkali is finding surfactants that can develop a low enough Interfacial Tension and low adsorption, or to find an acceptable adsorption mitigation strategy such as salinity gradient or adsorption inhibitors. In the early years of SP projects, very high surfactant concentrations were used (micellar process) and the process was not economic; as a result, alkali was seen as the only realistic solution. This appears to no longer be the case due to the developments of new surfactants. Although most projects in recent years have favoured the use of alkali, it seems that a trend towards SP is growing, with recent field projects in Kuwait, Oman, China and Russia favouring the SP solution. This paper will provide a discussion on the pros and cons of the use of alkali in surfactant-based processes. It will show that although using alkali has been a standard for many years it also entails severe surface issues such as scaling and requires additional capital for water softening and logistics. More importantly, recent developments in surfactants now seem to provide alkali-free solutions that can compete in terms of formulation performances. This now needs to be confirmed in the field.

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North Sabah EOR ADP – Examining the Challenges of Offshore ASP Development

Cited by 4 publications

References 7 publications

Optimization and comparison between polymer, surfactant-polymer and water flooding recoveries in a pre-salt carbonate reservoir considering uncertainties.

Optimization and comparison between polymer, surfactant-polymer and water flooding recoveries in a pre-salt carbonate reservoir considering uncertainties.

Evaluation of Seawater Based Surfactant Polymer Formulation in a Single Well Test Offshore

Surfactant Polymer SP vs. Alkali-Surfactant Polymer ASP: Do We Need the a in ASP?

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