Cost-Effective Life-Cycle Profile Control Completion System for Horizontal and Multilateral Wells

Ogoke, Victor; Aihevba, CeLeste Osasere; Marketz, Franz

doi:10.2118/102077-ms

Cited by 7 publications

(1 citation statement)

References 9 publications

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“…liner with expandable zonal inflow profiler (EZIP) tools can be used in a 6 1 ⁄8-in. hole (Ogoke et al 2006). An annular seal is created entirely by swelling of the seals.…”

Section: Expandable Tubular Solutionmentioning

confidence: 99%

Expandable Tubular Completions for Carbonate Reservoirs

Marketz¹,

Welling²,

Noort

et al. 2007

SPE Drilling &Amp; Completion

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A major Middle East operator has applied expandable tubular solutions for water shutoff and zonal isolation in fractured carbonate reservoirs. In this paper, we review the operator's experience with the implementation of this emerging well technology. Expandable tubular solutions have proven successful in terms of installation reliability, isolation of fractures, and zonal isolation without cement to segment horizontal wells.Case histories highlight the benefits, risks, and performance of expandable tubular completions. Post-installation production performance proves the viability of mechanical inflow profile control for better management of unwanted production of water in fractured carbonate reservoirs. 1. The OHC is set at the wrong place.2. A shutoff is carried out successfully, but the resulting profile modification does not deliver more oil and/or less water from the well.3. The OHC leaks. Scenario 1 can occur becaue of uncertainty of the location of the water influx. Because OHC is a nonreversible shutoff method,

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“…liner with expandable zonal inflow profiler (EZIP) tools can be used in a 6 1 ⁄8-in. hole (Ogoke et al 2006). An annular seal is created entirely by swelling of the seals.…”

Section: Expandable Tubular Solutionmentioning

confidence: 99%

Expandable Tubular Completions for Carbonate Reservoirs

Marketz¹,

Welling²,

Noort

et al. 2007

SPE Drilling &Amp; Completion

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Inflow Profile Control in Horizontal Wells in a Fractured Carbonate Using Swellable Elastomers

Welling¹,

Marketz²,

Moosa³

et al. 2007

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractA fractured carbonate field is developed via Gas Oil Gravity Drainage in the upper layers and water flood in the deeper layers. Due to the injection of gas and water into this fractured reservoir, horizontal wells tend to gas or water out, impairing the matrix drainage process. Different well and reservoir management techniques are used to prevent this from happening or to control the inflow when it happens. One such technique is to segment the bare foot horizontal open hole section with swellable rubbers and create up to 6 discreet zones of inflow, separated by 3 1/2 " tubing. The inflow from each section is currently controlled by a coiled tubing operated sliding sleeve. In the future it is anticipated that control will be done using hydraulically operated sleeves.Up till November 2006 eight horizontal barefoot oil producers have been re-completed with swellable packers. This paper concentrates on water shut-off and addresses the design, installation risks and mitigation, the impact of zone shut-off on well production performance, and the actions taken to optimize the production of each well by logging the well and shifting the sleeves.

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Improved Well and Reservoir Management in Horizontal Wells Using Swelling Elastomers

Al-Mahrooqi¹,

Marketz²,

Hinai³

2007

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Petroleum Development Oman (PDO) is producing substantial amounts of unwanted water or gas from most of its oil fields. To increase recovery from maturing reservoirs, PDO is developing the capability to detect and shut-off unwanted water and gas. Swelling elastomers have been deployed to segment horizontal wells in combination with surveillance and shut-off technologies. In beam pump wells dual wellheads have enabled logging while pumping. A key element to achieve improved oil recovery through well and reservoir management in a horizontal well is segmenting the well into different flow units. Swelling Elastomers (SE) are being deployed to enable segmentation. SE tool provides zonal isolation through the swelling of the elastomers when contacting produced water in the wellbore. In clastic reservoirs the completion philosophy has been changed from drilling minimum functionality wells to wells with closed-annulus completions that allow for surveillance and interventions. Surveillance is done in the drilling phase with under-balanced drilling and other open hole logging measurements. In the work over phase unwanted flow segments have been detected by logging while pumping coupled with greater integration of available reservoir data. Mechanical segment shut-off methods have been used. To date PDO has segmented more than 100 horizontal wells with swelling elastomers. In more than 20 wells suspected water producing feature were isolated at the initial completion stage and the rest were segmented based on reservoir flow unit characterization. After having proved that SE is delivering value in initial water shut off, the strategy is to prove a viable surveillance technique to identify water entry point in horizontal wells, and to develop several reliable water shut off (WSO) techniques depending on which segment's to be closed and if reversibility is required. To date more than one million barrels of oil have been realized as a result of the initial isolations as well as subsequent water shut offs. This paper is a continuation to the work presented in SPE paper number 91665 and will present case histories of the delivery and management of wells with swelling elastomer in clastic reservoirs in Oman. Introduction The South fields are located in southern Oman is in fact a group of six fields. Most of them are mature oil fields operated by Petroleum Development Oman. The fields produce medium gravity viscous crude with viscosity ranging from 200–550 cp. Reservoir pressure is maintained by infinite bottom water drive. The fields have been producing since mid 1980's. Initial fields' development was via vertical wells however, since the mid 1990's development has been primarily with horizontal wells. Production is from a combination of Aeolian and glacial sediments. Reservoir heterogeneity is high especially in the glacial Alkhalata reservoir. These fields accounts for more than 10% of total PDO production and is produced from almost 500 active wells. The current field water cut is about 93%. South field wells have different design. Almost all South field wells must have sand control. The horizontal reservoir section is about 350–500m long. The horizontal section may cross both reservoirs (Alkhalata and Aeolian Amin reservoirs). The horizontal section is drilled with a 61/8" drill bit and completed with stand-alone 4½" sand control liner using 200 micron wire-wrap screens (WWS) in open hole. This results in an open annulus between the sand control liner and the formation. More than 90% of well are artificially lifted via beam pump (BP) hence hindering accessibility due to surface units and rods. In the early development phases it was assumed that water production is simply a result of conning, and water is produced through matrix and all faults fractures are assumed to be sealing. However since the start of infill drilling in 1999, the new oil production has been historically dominated by high initial BSW levels and as of 2002 new wells produced cumulative average of three barrels of water for every one barrel of oil during their first year of production.

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Cost-Effective Life-Cycle Profile Control Completion System for Horizontal and Multilateral Wells

Cited by 7 publications

References 9 publications

Expandable Tubular Completions for Carbonate Reservoirs

Expandable Tubular Completions for Carbonate Reservoirs

Inflow Profile Control in Horizontal Wells in a Fractured Carbonate Using Swellable Elastomers

Improved Well and Reservoir Management in Horizontal Wells Using Swelling Elastomers

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