Marco Polo Deepwater TLP: Completion Implementation and Performance

Burman, Jack; Renfro, Kevin; Conrad, Mark

doi:10.2118/95331-ms

Cited by 4 publications

(1 citation statement)

References 16 publications

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“…The cost of a sand control remediation or a recompletion would by far outweigh the incremental cost of installing CHFPs or OHGPs in place of the more economical stand-alone screen techniques (King et al, 2003;Healy, 2012). Sand control completions currently installed in different deepwater fields by different operators (Table 2) show that the great majority in producer wells are OHGPs or CHFPs (Burman et al, 2013). In special cases where the formation is highly unconsolidated, an OHGP sand control method can be utilized.…”

Section: Discussionmentioning

confidence: 99%

Multiple Zones Completion Using a Proactive Algorithm for a Liquid Rich Deep-water Gas Well

et al. 2015

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With increasing number of deep water discoveries, the key issue is to develop new completion design philosophies and technologies that will lead to new levels of efficiency and reliability in completion design, safety, and environmental aspects. Deepwater fields are often associated with high pressures as well as additional down-hole problems such as shallow-water or gas flows, sand production, heavy oil, hydrates, paraffin-rich oil, and asphaltene deposition during drilling, completion and production. This provides new challenges for producing hydrocarbon from reservoirs located below such water depths. Intelligent completions, although complex and costly, are serving as an effective way of reducing many of the risks associated with reservoir uncertainties and their use justified in deep water and subsea environments. In this work, we incorporated intelligent well completion using a generated proactive algorithm in the design of a lower (multiple zones) completion for a liquid rich deepwater gas well discovered in a field 1800m of water and 250km from the shore. The field reservoir is susceptible to sand production, hydrate and scale formations -with a series of stacked channels with average porosity of 28 pu, and average permeability of 900 mD with each channel sequence approximately 10 -15m thick. Key aspects of the design considered include cased hole gravel packing to curb sand production; an injection mandrel for the injection of methanol and scale inhibitors and the use of interval control valves (ICVs) and permanent down hole gauges. The proactive algorithm proposed in this study aid in the effective control of the ICVs in order to achieve controlled flow and also in monitoring down hole pressure and temperature.

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Section: Discussionmentioning

confidence: 99%

Multiple Zones Completion Using a Proactive Algorithm for a Liquid Rich Deep-water Gas Well

et al. 2015

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Independence Project Completion Campaign: Executing the Plan

Burman¹,

Kelly

Renfro

et al. 2007

SPE Annual Technical Conference and Exhibition

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The Independence Project is a world-class subsea tieback development of 10 natural gas fields in the ultra-deepwater of the Gulf of Mexico. Anadarko is presently the operator of eight of the fields, in which 12 wells were pre-drilled to develop the resources. Completion operations began in early 2006 and were finished in early 2007, during which seven single-zone wells, three two-zone intelligent wells, and two three-zone intelligent wells were completed and flow tested from the Transocean Deepwater Millennium drillship. This paper will document an overview of the Anadarko 10-well completion campaign, during which numerous water depth and completion time records were set, utilizing innovative procedures and downhole designs to safely complete the project significantly ahead of schedule. Rig and BOP modifications, teamwork, effective communication, and novel solutions that positively impacted program effectiveness will be discussed. Background The ultra-deepwater Independence Project1 in the eastern Gulf of Mexico (Refer to Figure 1) will produce 1 billion cubic feet per day of previously stranded natural gas in record water depths of 8,000–9,000 feet (ft), adding approximately 2 percent to the U.S. supply of natural gas and 10 percent of natural gas supplied by the Gulf of Mexico. Located in an area devoid of gas processing and export infrastructure, the project exemplifies the ability of unprecedented collaboration, communication and creative application of technology among multiple producers and vendors to commercialize a significant resource base of 10 fields that would have been uneconomical to develop on a standalone basis. The Independence Project comprises 10 subsea fields: Atlas, Atlas NW, Cheyenne, Jubilee, Merganser, Mondo NW, San Jacinto, Spiderman, Q, and Vortex. Field discoveries occurred between 2001 and 2005. Producing companies that originally had interests in the 10 fields include Anadarko, Dominion (acquired by ENI), Kerr-McGee (acquired by Anadarko), Spinnaker (acquired by Hydro) and Devon. These producers, known collectively as the Atwater Valley Producers (AVP) group, began working together in 2003 to leverage their combined deepwater experience toward a common goal of achieving the fastest and safest path forward to first production. Refer to Table 1, Independence Project Completions by Operator and Figure 2, Independence Project Project Layout. The project's ambitious, accelerated completion campaign was planned to span two hurricane seasons in an area characterized by loop and eddy current issues year round. By working closely with contractors and vendors to push proven technologies to new limits, the first 12 wells (two Kerr-McGee and 10 Anadarko-operated completions) were completed ahead of budget; with no lost-time accidents or regulatory incidents. Additionally, sufficient rig days were saved to avoid a second hurricane season. In the process, a number of industry "firsts" and records were established. A significant contributor to the success of the completion campaign was application of technologies applied and lessons learned from Anadarko's successful Marco Polo Gulf of Mexico deepwater tension leg platform development1. Project Overview The Independence Project2 is located in the eastern Gulf of Mexico, 185 miles southeast of New Orleans, Louisiana, in Mississippi Canyon block 920. The hub-and-spoke development will produce and process natural gas from 10 fields in 8,000–9,000 ft water depths, with the longest tie-back exceeding 72 km (45 mi). The project consists of four components - the gas fields, the subsea system, the Independence Hub processing platform and the Independence Trail export pipeline. The platform is owned by Enterprise Products Partners (80 percent) and Helix Energy Solutions (20 percent) and operated by Anadarko. The pipeline is 100 percent owned and operated by Enterprise. The wells and subsea system are 100 percent owned and operated by the producing companies that have interests in the fields. The first discovery in the project was made in late 2001 in the Merganser field. The last of the 10 fields to be discovered was the Q field, in 2005. The first five development wells were drilled, cased and ready to complete by December 2004. The final development wells were drilled by May 2006.

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Dual Activities without the Second Derrick— A Success Story

Selamat

Webb

Fletcher

2008

IADC/SPE Drilling Conference

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Kikeh Field is located 120 km from Labuan in offshore Sabah Malaysia. The field, with 1330 m water depth, is the first deepwater development in Malaysia and consists of subsea and SPAR development wells. The West Setia is a non-propelled Semi-Submersible Drilling Tender being used for SPAR development activities. The Drilling Tender utilizes six stability columns supported by a twin-hull configuration. However, the derrick and partial rig package still sits on the SPAR (or platform deck) to carry out drilling and completion operations. The completion program covers not only standard scope of installation, i.e. lower, middle and upper completion, but also includes displacing fluid with nitrogen for riser dewatering and well clean up and testing. Several logging operations also were identified as tasks to be delivered during completion operations. Considering the wide scope of completion work outlined in the program, a detailed work assessment was conducted focusing on areas where offline activities could be conducted safely and efficiently. As a result of the assessment, at least seven completion-related activities were identified. During the first batch of SPAR completions which involved five wells, the result showed that the following activities were successfully completed offline, allowing the rig to be utilized for critical path operations:Tubular make up and racking backTree installationRiser annulus dewateringSetting/testing Mudline Hanger Packer (MLHP)Installation of flowline jumper and umbilicalClean up and flow testing the wellCement and reservoir evaluation loggingProduction Riser Tensioner installation and commissioningCycling and opening Formation Isolation Valve (FIV) This paper will describe in detail each of the operations involved, discuss rig capabilities and limits, and explain the challenges, safety considerations and lessons learned from the project as well as the time savings and value created from each of the activities.

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Marco Polo Deepwater TLP: Completion Implementation and Performance

Cited by 4 publications

References 16 publications

Multiple Zones Completion Using a Proactive Algorithm for a Liquid Rich Deep-water Gas Well

Multiple Zones Completion Using a Proactive Algorithm for a Liquid Rich Deep-water Gas Well

Independence Project Completion Campaign: Executing the Plan

Dual Activities without the Second Derrick— A Success Story

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