The Application of Flux-Based Sand-Control Guidelines at the Na Kika Deepwater 
Fields

Keck, R.G.; Colbert, Jason; Hardham, William

doi:10.2523/95294-ms

Cited by 4 publications

(2 citation statements)

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“…The US GoM contains many gas wells with relatively productive sand control completions 30,1,31 , however one of the largest gas fields discovered is the Mensa field and when originally full, contained slighltly less than 1.0 Tcf of recoverable gas. This makes comparison to recent large gas discoveries a stretch.…”

Section: North Americamentioning

confidence: 99%

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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Section: North Americamentioning

confidence: 99%

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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“…For the situations of perforations, screens and slotted liners, the data available (Keck et al 2005) show that erosion failure occur below a C -factor of 60. That is at the time the maximum safe operating limit for cased-hole and sand control completions.…”

Section: Screen or Slotted Liners Erosionmentioning

confidence: 99%

Sand Control Methods

Matanović

Čikeš

Moslavac

2011

Sand Control in Well Construction and Operation

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Completion Robustness as a Production Management Tool: Case History in a Mature Offshore Field

Rodrigues

Medeiros²,

Quitar

et al. 2009

Latin American and Caribbean Petroleum Engineering Conference

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There is an ever present demand for increasing or maintaining the oil and gas production, on a production unit basis. Thus, it is very important to have a method to define the maximum safe production rate from the completion point of view. In recent years some oil companies introduced sophisticated integrated asset models for production optimization which include well quality assessment and surveillance. This approach allows a quasi-real time production optimization. This paper introduces the concept of completion robustness, related to the maximum safe production rate, and applies it in a low level of well surveillance floating production unit. Some relevant aspects of the production unit regarding the wells are: subsea completions, a broad range of sand exclusion systems, and most of the wells are on stream for seven years. The paper presents the completion robustness concept, the general method to apply it, and the procedures developed for the specific case study, in which the connectivity between the formation and the well through the sand exclusion system plays an important role. The main product attained is a list ranking the wells in terms of completion robustness. Based on this list the asset team can decide which wells may support a production increase, which wells must be kept in the current status, and which wells need an intervention or a rate reduction. The main conclusions achieved are: the completion robustness concept is a rational approach to define maximum safe production rate per well from the completion point of view; the method and procedures developed, although suitable for production units with high level of reservoir and well key parameters surveillance, can also be applied to low level of surveillance ones; the use of the completion robustness by the production operations teams have the potential to increase the production output and the wells longevity. Introduction Many developing projects offshore Brazil demands fewer wells per project for economics reasons. Designing high-rates offshore wells for maximum safe production rate (MSPR) is a challenge. In Campos basin a large number of wells completed with sand exclusion systems (sand control wells) are on stream for seven years or more. Establish the MSPR for these wells, considering various degrees of degradation, is also a big challenge. This study introduces the concept of completion robustness (CR), which is related to MSPR, and applies it in a case study on sand control wells hosted in a production unit with low level of reservoir and well parameters surveillance. In Campos basin over 150 inside casing gravel packs (GP), above 150frac packs (FP), and more than 250 horizontal openhole gravel packs (OHGP) and a few cases of stand alone screens (SAS) have been installed to date (Neumann et al. 2002; Marques et al. 2007). Despite this significant number of sand control wells it was not possible to find a criterion, better than a drawdown limit, to define MSPR based on these wells analyses. The main reasons for that are:there were relatively few sand exclusion systems failures in Campos basin;most of the failures were "infant" failures or late life failures after repeated treatments for damage removal;there are a large number of intervenient variables;a few successful wells may have never required gravel pack installation;strong cyclic loads, such as water hammer, are difficult to track;some missing data caused by poor reports and several information system changes along the time. Tiffin et al. (2003) presented a method for determining MSPR based on analysis of over 200 sand control wells. Their analysis indicated that screen erosion was certainly the most frequent failure mechanism for cased hole frac-pack and gravel pack. They introduced a criterion based on an erosion factor for determining MSPR for these completions and maintained the drawdown limit for OHGP completion. The erosion factor is the product of the square root of fluid mixture density and the flow velocity exiting the perforation tunnel, vc. Their results showed that for gas well the start of high failure rate occurred for vc around 20 ft/sec, while this value is about 10 ft/sec for oil wells.

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The Application of Flux-Based Sand-Control Guidelines at the Na Kika Deepwater Fields

Cited by 4 publications

References 0 publications

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

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

Sand Control Methods

Completion Robustness as a Production Management Tool: Case History in a Mature Offshore Field

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