Critical Offshore Field Development Projects –Why Work Outside of Strict Timelines?

2020 ◽  
Author(s):  
James Ohioma Arukhe ◽  
Saleh Abdullah Al-Ghamdi ◽  
Musa Mohammed Al-Nafisah
Keyword(s):  
Development Projects ◽  
Field Development ◽  
Offshore Field

Approach for Effective Design and Cost Estimation of New built / Conversion FPSO (2014)

2014 ◽  
Author(s):  
Upendra Malla ◽  
Krishna M. Karri
Keyword(s):  
Cost Estimation ◽  
Structural Design ◽  
Effective Means ◽  
Step Method ◽  
Support Design ◽  
Field Development ◽  
Early Stages ◽  
The Cost ◽  
Offshore Field ◽  
Effective Design

Floating Production Storage and Offloading (FPSO) sizing and cost estimation has become a challenging task at the early stages of offshore field development. During the early stages of field development designer needs to size and estimate cost in order to decide feasibility of the project. This paper describes a step by step method used to size and estimate the cost of a new built (or) converted FPSO based on basic engineering, existing FPSO data and corresponding metocean criteria for a particular location. This step by step approach covers FPSO sizing, hull structural design, mooring sizing, topsides support design and steel renewal using offshore classification rules and regulations. FPSO cost is estimated based on the design particulars (i.e. hull weights, FPSO particulars, mooring sizes etc.) and current market unit rates. This approach is an effective means to size and estimate cost of an FPSO at early stages of field development which saves overall time and cost for a client.

Offshore Field Development

2019 ◽  
pp. 207-212
Author(s):  
Shashi Shekhar Prasad Singh ◽  
Jatin R. Agarwal ◽  
Nag Mani
Keyword(s):  
Field Development ◽  
Offshore Field

An Integrated Approach to Optimise an Offshore Field Development Plan

2020 ◽  
Author(s):  
Hiren Kasekar ◽  
Usama Ghauri ◽  
Michael Nevin ◽  
Raphaele Mel ◽  
Mattheus Uijttenhout ◽  
...  
Keyword(s):  
Integrated Approach ◽  
Development Plan ◽  
Field Development ◽  
Offshore Field

TUBINGLESS COMPLETIONS IN THE SURAT BASIN

1976 ◽  
Vol 16 (1) ◽  
pp. 107
Author(s):  
M. A. Delbaere
Keyword(s):  
Oil And Gas ◽  
Small Diameter ◽  
Development Projects ◽  
Well Bore ◽  
Gas Wells ◽  
Oil And Gas Development ◽  
Gas Field ◽  
Field Development ◽  
Reservoir Stimulation ◽  
Well Completion

Oilfield operators have always looked for ways of reducing the costs of oil and gas development projects and especially when investment costs were critical to project economics. Tubingless completions have evolved over the last 30 years in North America to fill the need for reduced investment costs particularly in the case of fields with either limited reserves or limited profitability.Tubingless completions basically utilise small diameter tubulars to function as both production casing and flowstring. The tubulars are cemented in the borehole, not to be removed or recovered until the field is depleted and/or the well abandoned. The technique is limited in application to those fields with no corrosion or wax or hydrate problems and with a limited requirement for reservoir stimulation and workovers. The greater the number of operations performed within the tubingless well bore the greater the risk of losing the well.The main benefits of tubingless completions are as follows:Reduction in development well completion costs.Marginally productive hydrocarbon zones can be completed and tested.Completion of individual gas zones of multi-pay wells within their own permanently segregated flowstrings at much lower capital and operating costs.The experience this far with Kincora gas field development wells indicates the tubingless completion method to be completely feasible for gas wells drilled in the Surat Basin and possibly in other areas of Australia.

Mitigated Riser Response During Submerged BOP Move Through Use of Drillstring Active Heave Compensation System

2019 ◽  
Author(s):  
Lucas Cantinelli Sevillano ◽  
Celso Kazuyuki Morooka ◽  
Sigbjørn Sangesland
Keyword(s):  
Environmental Conditions ◽  
Development Project ◽  
Compensation System ◽  
Dynamic Responses ◽  
Substantial Part ◽  
Field Development ◽  
Drilling Rig ◽  
Deep Waters ◽  
Commercial Program ◽  
Offshore Field

Abstract Rig costs account for a substantial part of the total cost of an offshore field development project. Systems and methods that can reduce the non-productive time are therefore of interest to operators. In deep and ultra-deep waters, the duration of drilling campaigns with multiple, closely located wells may potentially be reduced by optimizing equipment-retrieving procedures between moving from one drilling location to another. This may be achieved by not retrieving the whole drilling riser and the BOP to the surface. Instead, retrieving just a few joints and navigating the drilling rig with the drilling riser and BOP suspended may save several days of rig time. Previous works on this topic have investigated the riser response during the move and delineated under which environmental conditions (waves and current) this operation may be safely executed. The axial displacement of the riser column may be of concern, and it has been presented that the hang-off condition may substantially influence the response of the riser. Instead of looking at the riser hanging either from the spider-gimbal or from the tensioners, this work proposes to use the active heave compensation system of the drillstring to more efficiently decouple motions of the rig from the riser during the move. Thus, mitigating the riser response and enabling the navigation with the suspended riser and BOP to take place under broader environmental conditions. A commercial program for computational simulations of the riser dynamic responses was used in the study presented in this paper. A representation of the active heave compensation drilling system and the tool used to achieve this purpose were added to the model. The responses of a typical riser used in deep water were determined under several environmental conditions, and the responses of different hanging systems were compared. Results indicate that the proposed approach for suspending the riser may decrease the dynamic forces and stresses during the rig move. The ability of the modeled rig equipment to withstand the move was also investigated.

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