Performance evaluation and optimization of the Kuparuk hydrocarbon miscible water-alternating-gas flood

Hallam, R.J.; Tuan, Doan Doan; Reinbold, Eric W.

doi:10.1144/gsl.sp.1995.084.01.16

Cited by 9 publications

(8 citation statements)

References 11 publications

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“…Results from 3D modeling of drillsite 2Z on the basis of the Todd-Longstaff 21 approach have been discussed elsewhere. 10 In that work, the mixing parameter, w, was adjusted to fit historical performance. It was implicitly assumed that the value remained constant for a variety of slug sizes.…”

Section: Discussionmentioning

confidence: 99%

“…9,10 The EOR response from the original project area, after accounting for the effects of subsequent infill drilling and well work, is clearly evident (Fig. 5).…”

Section: Smallćscale Eor (Sseor) Pilotmentioning

confidence: 99%

“…An extensive fieldwide refracturing program was initiated in 1988 to increase withdrawal from the less prolific A-sand. 7,8 An EOR pilot was initiated in 1988 on two drillsites, 9,10 and subsequently expanded to one of the IWAG drillsites in 1993 to test the MWAG after IWAG process. Largescale expansion of EOR at Kuparuk is in progress.…”

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confidence: 99%

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Kuparuk Large-Scale Enhanced Oil Recovery Project

Hoolahan

Mcduffie

Peck

et al. 1997

SPE Reservoir Engineering

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The Kuparuk River oil field has had a "miscible" water-alternatinggas (MWAG) enhanced-oil-recovery (EOR) pilot in place since 1988. This original pilot was implemented on two drillsites previously on waterflood. The pilot was expanded to a third drillsite in 1993 to test the MWAG process in an area previously flooded by an "immiscible" water-alternating-gas (IWAG) recovery technique. Large-scale application of MWAG at Kuparuk is in progress, with a project that will more than triple current MWAG injection. Full implementation is slated for mid-1996. When completed, the Kuparuk large-scale EOR (LSEOR) project will be among the largest of its kind in the world. This paper covers the basic aspects of moving the EOR process at Kuparuk from pilot to large-scale application. A number of hurdles had to be overcome, including scaleup of field and simulation results in a consistent manner and the need to use existing infrastructure to ensure economic viability.

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Section: Discussionmentioning

confidence: 99%

“…9,10 The EOR response from the original project area, after accounting for the effects of subsequent infill drilling and well work, is clearly evident (Fig. 5).…”

Section: Smallćscale Eor (Sseor) Pilotmentioning

confidence: 99%

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Kuparuk Large-Scale Enhanced Oil Recovery Project

Hoolahan

Mcduffie

Peck

et al. 1997

SPE Reservoir Engineering

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“…Third, from an EOR standpoint, short cycle WAGs can expect to have slightly better sweep efficiency. Short-cycle WAG attempts to mimic the simultaneous MI 13 and water injection that would, in theory, control MI movement more than the normal WAG process 14 . As a result, it can slightly improve MI sweep efficiency (and oil recovery) and trap more gas in the reservoir.…”

Section: Short Cycle Wagmentioning

confidence: 99%

Gas Management in a Large, Complex, Miscibly Flooded Oil Field

Dunn

Lagerlef

Chamberlain

2000

SPE Asia Pacific Conference on Integrated Modelling for Asset Management

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe Kuparuk River Field, on the North Slope of Alaska, is an extremely complex system when predicting and managing produced gas and artificial lift gas. Encompassing an area of almost 200 square miles, it is one of the largest full-field waterfloods in the world. On a daily volume basis, it is the second largest miscible gas flood in the world, second only to Prudhoe Bay. The field has approximately 400 gas-lifted wells and a dozen wells on ESPs. Currently, the field is characterized as "formation gas constrained" because wells over a formation GOR of ~6000 scf/bbl must be shut-in. Fluids are processed and gas is compressed at three different processing plants, with some processes being shared between plants, and other processes being independent. Combined with a reservoir that is composed of two distinctly different sands, makes reservoir management and particularly gas management, an extremely challenging task.

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“…al. 4 reviewed WAG application to oilfields worldwide and found increases in recovery ranging from 5 to 20%. Dalen et.…”

Section: Introductionmentioning

confidence: 99%

Injectivity and Gravity Segregation in WAG and SWAG Enhanced Oil Recovery

Faisal

Bisdom

Zhumabek

et al. 2009

SPE Annual Technical Conference and Exhibition

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Injectivity and Gravity Segregation in WAG and SWAG Enhanced Oil RecoveryA. Faisal AbstractGas-injection enhanced oil recovery can recover nearly all residual oil where the gas sweeps. Sweep efficiency in these processes is often poor, in large part because of gravity override of gas. Stone and Jenkins presented a model for gravity override in homogeneous reservoirs, showing that the distance gas and water travel before segregation depends directly on injection rate. In cases where injection pressure is limiting, injectivity is key to overcoming gravity override.Stone assumed continuous injection of gas and water as a model for WAG (Water Alternating Gas), contending that this is valid as long as slugs mix near the well. This model for co-injection can be extended to relate segregation distance for co-injection processes directly to injection pressure. Injectivity depends on saturations very near the well, however. Therefore, where injection pressure is limiting, this model is pessimistic because injectivity in WAG is greater than in co-injection.We investigate the increase in injectivity possible with WAG compared to co-injection in 1D and 2D, and the implications for gravity override in 2D, using a range of models for gas and water relative permeabilities. We confirm that the greater injectivity of WAG improves vertical sweep compared to Stone's model when injection pressure is limiting. The greatest improvements occur when slugs violate Stone's assumption: that is, when they are too large to mix fully near the well. The increase in injectivity over co-injection is greater for foam than for WAG without foam, because foam has much lower mobility when gas and water flow together.

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Performance evaluation and optimization of the Kuparuk hydrocarbon miscible water-alternating-gas flood

Cited by 9 publications

References 11 publications

Kuparuk Large-Scale Enhanced Oil Recovery Project

Kuparuk Large-Scale Enhanced Oil Recovery Project

Gas Management in a Large, Complex, Miscibly Flooded Oil Field

Injectivity and Gravity Segregation in WAG and SWAG Enhanced Oil Recovery

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