Completion Design, Installation, and Performance--Cannonball Field, Offshore
Trinidad

Healy, John M.; Powers, J.T.; Maharaj, Matthew; Ramlogan, Marsha

doi:10.2523/110524-ms

Proceedings of SPE Annual Technical Conference and Exhibition 2007

DOI: 10.2523/110524-ms

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Completion Design, Installation, and Performance--Cannonball Field, Offshore Trinidad

John M. Healy¹,

J.T. Powers

Matthew Maharaj³

et al.

Abstract: fax 01-972-952-9435. AbstractThe Cannonball field is a one Tcf gas condensate development offshore Trinidad producing at an initial rate in excess of 800 MMcf/D from three wells. The completion design selected was 7⅝ inch production tubing with an open-hole gravel pack (OHGP). The initial well (CAN01) has produced at an initial rate of 320 MMcf/D. The calculated deliverability of this well is 415 MMcf/D. This paper discusses the completion basis of design, detailed engineering assurance of the design, qualific… Show more

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Erosion Study for a 400 MMcf/D Completion: Cannonball Field, Offshore Trinidad

Healy¹,

Martin²,

McLaury

et al. 2008

All Days

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The Cannonball Field is a one Tcf gas condensate development offshore Trinidad producing at a sustained rate in excess of 800 MMcf/D from three wells. The completion design selected was 7" inch production tubing with an open-hole gravel pack. The initial well (CAN01) has produced at 333 MMcf/D. These rates are higher than typically experienced which has raised concerns concerns about the resultant potential for metal erosion. As a result, a rigorous erosion study was initiated. The objective was to quantitatively evaluate erosion at various rates over the life cycle of the well to appropriately design the completion and select the appropriate materials. The erosion nodes within the completion - changes in flow direction (e.g. a tee such as in the wellhead) and/or flow constrictions - were identified as: the tree; a landing nipple profile near the surface; and a formation isolation device (FID) positioned in the gravel pack assembly. The key parameters were defined as particles of sharp sand, with a diameter of 50 microns, at a concentration of 0.1 lbs/MMcf. Erosion rates were calculated using the erosion model - Sand Production Pipe Saver (SPPS) - developed by the Erosion/Corrosion Research Center, University of Tulsa, USA. Erosion rates were calculated over the life cycle starting at initial rates of 280 and 400 MMcf/D. Erosion rates were also calculated with and without a liquid film (a protective layer on the pipe wall that can reduce the erosion rate). Erosion results (without a liquid film) at all nodes exceeded BP's erosion limit; however, the erosion results with a thin liquid film were mostly below the company's erosion limit. Determination of the presence and thickness of the liquid film was critical. A multi-phase pipeline simulation calculated that a sufficient liquid film would exist at all critical areas. Erosion of the tree was further assessed by computation fluid dynamics (CFD) models, which identified several hot spots; thus, additional cladding of all flow-wetted surfaces and rounding of the outlet corner was required. The Cannonball completion design, including the tree, was determined to be capable of sustained rates up to a maximum 400 MMcf/D. The three (3) well development, where initial rates have been as high as 333 MMcf/D, has been on production for several years without any erosion issues. Introduction Trinidad's gas production has increased dramatically over the past 10 years. In 1996, local gas production exceeded oil production for the first time as the twin island Caribbean state of Trinidad and Tobago moved from a predominantly oil producing country to a major gas producer. The gas growth has been driven by an increase in local demand and construction of a liquefied natural gas (LNG) infrastructure, which now includes four Trains. BP Trinidad and Tobago LLC's (bpTT) share of the gas supply to the local market has grown from less than 350 MMcf/D in 1994 to over 2 Bcf/D by mid-2007 with production coming predominantly from several prolific gas fields located off Trinidad's East Coast. The Cannonball field is located approximately 35 miles off the southeast coast of Trinidad in 240 ft of water (Figure 1). The discovery well, Ironhorse-1 ST1, was drilled in 2002. In 2005, a minimal structure (nine slot four pile) production platform was installed and three development wells were drilled and completed with a jack-up cantilever drilling rig. Initial production commenced on March 12, 2006 following pipeline hook-up and commissioning. The Cannonball field was brought on production at a sustained rate in excess of 800 MMcf/D. A previous paper 1 presented a detailed review of the design, engineering assurance, installation and performance of the Cannonball completions.

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Erosion Study for a 400 MMcf/D Completion: Cannonball Field, Offshore Trinidad

Healy¹,

Martin²,

McLaury

et al. 2008

All Days

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One Tcf From One Well: The Design of a 500 MMscf/D Subsea Well for Offshore Mega Gas Fields

Reeves

Healy

2014

Day 2 Thu, February 27, 2014

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With the continued discovery of large gas fields worldwide that have highly prolific sandstone reservoirs, the ability to design wells capable of recovering ultra-high volumes of gas will become of great interest. The project teams for these fields will be challenged to develop the fields with the smallest well count possible. The results from this study could prove useful to production and completion teams supporting large gas field developments. This paper presents a study to determine the feasibility of a subsea sand control gas well producing at rates up to 500 MMscf/D and recovering one trillion cubic feet (Tcf) of gas. Because the size of recent gas field discoveries is so large, reservoir simulation models will show that recoveries exceeding one Tcf are possible from a single location. Considering the huge cost to install deep water subsea sand controlled wells, reducing the total well count necessary to deplete the field is a business imperative. The results of the study show that completing a sand control well that can produce 500 MMscf/D and recover one Tcf is plausible. The details of the well productivity, completion design concepts and relevant comparison of analogue fields is shown. In conclusion, production and completion engineers involved in development of mega gas fields should at least consider planning for such wells.

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Pushing the Completion Design Envelope in Ultra-Deepwater - Design, Installation, and Performance of Deep High Pressure Completions - A Case History of the Gunflint Development, Offshore Gulf of Mexico

Sanford

Healy

Hopper

et al. 2016

Day 2 Tue, September 27, 2016

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A Gulf of Mexico case history is presented that describes the successful delivery of two (2) deep (27,000-ft) high pressure (>17,500-psi) high rate design (25,000 BOPD) oil wells in an ultra-deep water (+6000-ft) environment. Well conditions, coupled with challenging production requirements (depletion of 10,000-psi), provided a very arduous design challenge. One well was completed as a single frac pack at 27,000-ft MD. The second well required a stacked frac pack at 25,000 ft-MD and intelligent flow controls. Twenty-seven (27) firsts, to the industry and / or Noble, were required to deliver the final completion designs. These firsts ranged, to name a few, from a new tieback casing material, a paradigm change in the Temporary Abandonment (TA) procedure (which yielded a cost savings of $15 million per well), a new perforating charge, qualification of a new material for the Gravel Pack (GP) packer, weighted frac fluids, changes in the upper completion designs, Vacuum Insulated Tubing (VIT) welding qualification and re-design of a control line Y-block. Any one item or any single technology gap, is seldom insurmountable. However, it is the layers and the multitude of challenges in these type of environments, where every component and their interdependencies are stretched to the edge of the design envelope that pushes the completion team and suppliers to their limit. All of these together make the goal of flawless execution very challenging. This paper will provide an overview from design thru operations, and highlight some of the engineering challenges and lessons learned. A field proven completion delivery process combined with a team of experienced people and rigorous procedures successfully designed and delivered two (2) complex completions that were on the edge of deep-water completion technology. Based on the Rushmore Review database, both wells (1 single GP and 1 single selective GP) were the fastest completions (when analyzed on a well depth basis) since Macondo. Both wells were completed in 2015, and are currently waiting on final hook-up and commissioning. First oil is forecast for July 2016. Industry will continue to explore ultra-deep water and discover deeper and higher pressure reservoirs that push the completion technology envelope. It is imperative that engineers be able to confidently design and deliver completions for this extreme environment that will achieve the productivity and reliability required by the project economics. The aim of this case history is to provide the engineer, faced with similar challenges, with information that may prove beneficial in the approach, method, design and delivery of these type of complex, critical completions.

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Completion Design, Installation, and Performance--Cannonball Field, Offshore Trinidad

Cited by 3 publications

References 4 publications

Erosion Study for a 400 MMcf/D Completion: Cannonball Field, Offshore Trinidad

Erosion Study for a 400 MMcf/D Completion: Cannonball Field, Offshore Trinidad

One Tcf From One Well: The Design of a 500 MMscf/D Subsea Well for Offshore Mega Gas Fields

Pushing the Completion Design Envelope in Ultra-Deepwater - Design, Installation, and Performance of Deep High Pressure Completions - A Case History of the Gunflint Development, Offshore Gulf of Mexico

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