Reservoir Fluid Sampling And Recombination Techniques For Laboratory Experiments

Strong, Jeff; Thomas, Fridtjof; Bennion, D.B.

doi:10.2118/93-54

Cited by 14 publications

(8 citation statements)

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“…In cases where the reservoir fluid is known to be highly under saturated, the target saturation pressure may be significantly lower than the actual reservoir pressure and therefore the separator GOR may be a better reservoir fluid characteristic to attempt to match (Strong et al, 1993).…”

Section: Recombinationmentioning

confidence: 99%

Investigation of gas injection flooding performance as enhanced oil recovery method

Bayat

Lashkarbolooki

Hezave

et al. 2016

Journal of Natural Gas Science and Engineering

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Section: Recombinationmentioning

confidence: 99%

Investigation of gas injection flooding performance as enhanced oil recovery method

Bayat

Lashkarbolooki

Hezave

et al. 2016

Journal of Natural Gas Science and Engineering

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“…Given that field X is a saturated reservoir, the first and third methods are not suitable methods for recombination because of high uncertainties in determining the fraction of gas attributed to the gas cap gas and to solution. Moreover, according to a review by Strong et al (1993), the bubble point pressure technique is a better technique for saturated oil reservoirs. Hence the bubble point pressure method was carefully chosen for this study.…”

Section: Reservoir Fluids Preparationmentioning

confidence: 99%

Designing of Successful Immiscible Water Alternating Gas (IWAG) Coreflood Experiment

Khanifar

Raub

Tewari

et al. 2015

Day 4 Wed, December 09, 2015

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Average recovery factor in offshore field under discussion is relatively moderate due to wider well spacing and poor sweeping efficiency thus leaving significant volume of oil behind in the reservoir. Timely application of EOR is therefore necessary to enhance the recovery factor to a reasonable level. Among the various EOR processes and techniques of EOR screened, studies found immiscible water-alternating gas (IWAG) injection as the most suitable and viable option for this Malaysian mature offshore oilfield. Realistic estimate of incremental oil by EOR is paramount as IWAG application involves high CAPEX and OPEX project. Therefore, representative is required to be generated in the laboratory for constructing a realistic reservoir simulation model to understand the three phase flow in porous media and support the IWAG process for full field implementation. Important parameters in this case are residual oil saturations in sequential injection of displacing fluids water and gas and trapping of gas, injection volumes and frequency of alteration. Therefore, IWAG core flooding experiments under reservoir conditions need to be performed, results quantified and parameters for hysteresis modeling established.This paper addresses the challenges and strategies of IWAG core flooding experiment performed under reservoir conditions using representative composite native cores, live reservoir oil sample, field produced gas sample and synthetic formation brine water. The laboratory injection rates are considered equivalent to the field fluid advance velocity like in any standard displacement steps. Also, gravity stable injection mode is considered to achieve the best IWAG displacement performance. These challenges and strategies are drawn from lessons learned during accomplishment from earlier IWAG core flooding experiments. The IWAG core flooding experiments were performed on composite field core samples, arranged according to Langaas method, using current field production gas with 60 mole % CO2. The composite reservoir core samples were initially saturated with live oil and irreducible formation water and then flooded with formation water and seawater to residual oil saturation at reservoir conditions. Following, waterflooding, a number of water and gas cycle slugs were injected. The displacements were conducted at pressures well below the estimated minimum miscibility pressure during these experiments. Laboratory studies and numerical simulation study conducted on the applicability of immiscible WAG injection using high CO2 content produced gas indicated that 7.0 % additional oil recovery over waterflooding period can be recovered.

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“…They give a series of correlating charts to predict the amount of stock tank oil from a given fluid. Strong, Thomas, and Bennion (1993) and a host of others discuss the recombination technique, but focus primarily on lab recombination and on obtaining insitu representative fluid compositions. Statoil (1984) provide detailed documentation on a procedure to perform "split-phase" process simulation to obtain accurate equilibrium phase data under precise pressure/temperature conditions and, from recombination calculations, to produce detailed and representative wellstream compositions.…”

Section: Literature and Software Surveymentioning

confidence: 99%

Well Test Rate Conversion to Compositional Wellstream

Hoda¹,

Whitson²

2013

SPE Middle East Oil and Gas Show and Conference

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Well test rates are measured with test separators operating at varying pressure and temperature during initial production tests for a new well and during periodic tests used to monitor well performance and allocate multi-well production separator rates.Converting test separator gas and oil volumetric rates to a common (fixed) set of surface separator conditions is useful to ensure consistent history matching and rate allocation, development of valid inflow performance relations, and correlating well performance changes over time. This paper provides a method to convert reported test rates to a molar compositional wellstream rate. This compositional wellstream will exactly reproduce the reported test rates at the separator conditions prevailing when rates were measured. The compositional wellstream rate can then be re-processed through a fixed set of separator conditions to provide total surface gas and stock-tank oil rates.The requirements for converting test rates to a compositional wellstream include: (1) an appropriate EOS model, (2) an estimate of the wellstream composition -the "seed feed", (3) test separator volumetric rates, and (4) test separator conditions of pressure and temperature. The seed feed is usually the previously-determined wellstream composition from an earlier test. The seed feed is flashed at test separator pressure and temperature, resulting in equilibrium gas and equilibrium oil compositions. These equilibrium compositions are recombined in a ratio that yields exactly the test separator gas-oil ratio with the EOS model, thereby yielding wellstream composition. Properties of the separator phases are used to convert separator volumes to moles and thereby wellstream molar rate.Sometimes a similar conversion is needed for volumetric gas and oil rates resulting from a multi-stage separation process. An important example is conversion of black-oil rates to compositional wellstreams, where the black-oil PVT tables have been generated from a multi-stage separation process.Finally, we discuss the processing of compositional wellstreams through a higher-level (group, field, or asset) process facility that takes into account the total feed composition of the process facility, and how to back-allocate well contributions of total product rates.

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Reservoir Fluid Sampling And Recombination Techniques For Laboratory Experiments

Cited by 14 publications

References 0 publications

Investigation of gas injection flooding performance as enhanced oil recovery method

Investigation of gas injection flooding performance as enhanced oil recovery method

Designing of Successful Immiscible Water Alternating Gas (IWAG) Coreflood Experiment

Well Test Rate Conversion to Compositional Wellstream

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