Multi Type Application of Cement-Packer: Simple and Economic Method of Accessing By-Passed Reservoir Potential

Idris, Muhammad; Rylance, Martin; Joenoes, Krisjahbana; Abidin, Nanang Firmansyah; Supriyono, Anton

doi:10.2118/108973-ms

Cited by 8 publications

(1 citation statement)

References 2 publications

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“…The zones are then perforated through the cemented tubing and casing annulus and put on production. This technique (Susilo et al 2001;Idris et al 2007) provides a cost-effective solution with a quick turnaround time to complete and develop marginal reservoirs. Therefore, the cementing objective for Well BB-1 was simply to provide zonal isolation from above and below the identified production zones.…”

Section: Zonal Isolation Considerationsmentioning

confidence: 99%

Cost-Effective Recovery of Bypassed Reserves Using Rigless Cement Packer Completion Technique: Case History from Offshore Egypt

et al. 2013

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In many Brownfield developments, toward the end of a well's life cycle, the primary production zone(s) commonly waters out or depletes, or the well sits idle with no alternative means of returning back to production. At this stage, as a normal course of action, the wells are re-evaluated for potential reserves that might have been bypassed during the original completion. For zones that do not appear promising or could be marginal in terms of delivery, the recompletion costs can be prohibitive. It is in such situations that "cement packer" completions performed rigless in offshore environments provide an economic alternative to workover operations. This technique can be cost-effective and has the potential to increase the producing life of a well. This paper describes the successful application of a "cement packer" to recover bypassed reserves located above the production packer in an offshore field in the Mediterranean Sea. The technique allows zonal isolation between the various upper zones by placing cement slurry in the production tubing and casing annulus.Conceptually, it might appear simple to perform such a job, but the planning and execution must be well formulated to ensure well integrity is maintained at all times. In this case history, the challenges of executing the job were examined from many different angles (i.e., high angle well, small platform, short weather window for operations, and multiple job sequences). The average cost was only 20 to 60% of conventional workover jobs, which is a savings of up to USD 400,000. The production results have also been encouraging. These successful results have revealed opportunities for reactivating many more shut-in wells with bypassed reserves that are currently considered economically marginal. BackgroundWell BB-1 was drilled in 1997 during the exploratory drilling phase of the Petro-Said field in the Mediterranean Sea, offshore Egypt (Fig. 1). The well was completed in 2005 in the Kafr el Sheikh Anomaly-4 (An-04) level from 1710.0 to 1755.0 m with an internal casing gravel pack to help prevent formation sand production. With time, the primary production zone (An-04) depleted and watered-out, and it remained idle for further development. There were a few limited shallower zones (An-02 and M1) higher up in the wellbore, above the production packer, that appeared worth investigating. These zones were small sands with possibly low static bottomhole pressure; otherwise, scarce information was available regarding their production capability. The upper completion string consisted of a 4.5-in. chrome tubing (Fig. 2) run to surface on a 9 5/8-in. completion packer set at 1648 m. A landing nipple was available in the string at 1645 m and a subsurface safety valve at 215 m. The lower completion included a gravel-pack packer set at 1675 m and a gravel pack screen and gravel across the perforated interval at 1710 to 1755 m.The recompletion of this well using an offshore workover rig would have entailed killing the well, isolating the lower completion, pulling the upper co...

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Section: Zonal Isolation Considerationsmentioning

confidence: 99%

Cost-Effective Recovery of Bypassed Reserves Using Rigless Cement Packer Completion Technique: Case History from Offshore Egypt

et al. 2013

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Managing Reservoir and Operational Decline without a Rig: An Okan Case Study

Ogbuagu¹,

Afolayan²,

Esan³

et al. 2017

Day 3 Wed, August 02, 2017

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The objective of this paper is to share learnings from the Okan field, highlighting successful strategies adopted to mitigate reservoir and operational decline almost 8 years without producer drilling or major rig workovers. Value gained is quantified to show that over a third of the current Okan production is tied to strategies adopted during the period of interest. Details of the different wellwork methodologies are provided to communicate how value was maximized using minimal cost. Key strategies adopted that have created the Okan success story over the period of interest include the jacket-centric rigless wellwork approach which has resulted in a drop in overall wellwork costs as multiple wells on the same jacket are worked over in one mobilization. The use of interwell gas lift systems for isolated jackets unlocked reserves that would otherwise be uneconomic because of costly pipelay. In addition to enhancing production from wells requiring gas lift, the conversion of idle oil line conversions to gas supply lines for gas lift ensured available facility assets are utilized, bringing pipelay savings as well as production gain. Also, taking full advantage of the Okan Gas Gathering and Compression Platform, production from reservoirs with high GOR has been optimized, resulting in oil and gas gain without routine gas flaring. Challenges encountered and lessons learned are also shared in this paper. As a result of the strategies shared in this paper, the current Okan production is over 30% higher than what it would have been without the deployment of these strategies highlighted. The same strategies can be transferred to other assets to obtain optimum value in these times of low commodity prices.

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Accessing New Pay Intervals in the Tubing-Casing Annulus Above Top Packer with Cement Packer Technology, S Field, Peninsular Malaysia

Johan

Zayani

Moritz

et al. 2018

SPE Annual Technical Conference and Exhibition

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As a low-cost alternative to expensive rig workovers, placement of a cement packer between tubing and casing has been previously applied in Malaysia. The purpose is to create a new annular barrier above the existing production packer to gain access to behind-casing opportunities (BCOs) or pay zones, removing the need for a workover. These pay zones, usually with minor or unknown production potential, have been left by the operator during initial completion because there were larger pay zones in deeper reservoirs. Cement packer placement can be achieved using basic intervention equipment as opposed to more expensive workover units. The cement packer technique eliminates the need of recompleting the well with a conventional workover rig and reduces operational complications together with cost. There are different methods to deploy a cement packer. The highest chance of success, particularly when larger volumes of cement are needed, is using coiled tubing (CT) as the primary method to place the cement slurry in the tubing/casing annulus. In this method, a cement retainer was used and conveyed with CT. CT provides the ability to sting into the retainer and cement being displaced through the coil, ensuring all completion accessories have no contact with cement slurry which can impair their functionality, and also prevents U-tube effect of the slurry once cement is placed behind the tubing. After the cement is set, a cement bond log (CBL) is run to confirm cement integrity behind the completion tubing before adding new perforations. This paper presents the successful cement packer placement operation with the help of the CT executed on an offshore platform in Peninsular Malaysia. A potential pay zone of the I-Group reservoir was discovered in the field after running pulsed-neutron cased-hole saturation logging tools, which are situated above the production packer; appraisal was required because of the unknown fluid type. Close collaboration among various parties in candidate selection, job preparation and design, cement laboratory testing, and operational planning and execution, were keys to the success of this pilot operation. By proving operational feasibility and economics, the technique opened up additional opportunities in restoring idle wells with bypassed reserves within the same field.

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Multi Type Application of Cement-Packer: Simple and Economic Method of Accessing By-Passed Reservoir Potential

Cited by 8 publications

References 2 publications

Cost-Effective Recovery of Bypassed Reserves Using Rigless Cement Packer Completion Technique: Case History from Offshore Egypt

Cost-Effective Recovery of Bypassed Reserves Using Rigless Cement Packer Completion Technique: Case History from Offshore Egypt

Managing Reservoir and Operational Decline without a Rig: An Okan Case Study

Accessing New Pay Intervals in the Tubing-Casing Annulus Above Top Packer with Cement Packer Technology, S Field, Peninsular Malaysia

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