An Evolution From Smart Wells to Smart Fields

Steen, Erik van der; Knoppe, Ronald

doi:10.2523/100710-ms

Cited by 2 publications

(1 citation statement)

References 0 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Figure 1 shows the production flow to the SCOT East Asset CDU tank to a selected set of wells in the Champion West field. Some of the Champion West wells happen to be smart wells with zonal production allocation requirements (refer to [19], [20] and references therein). An example snapshot of the system tracking upstream from the CDU outlets to the wells is presented in the Figures 2, 3, 4, 5, 6.…”

Section: Real Time Surveillance Of East Asset Offshore Production Liqmentioning

confidence: 99%

Asset-Wide Reconciled Production Monitoring—A Key Enabler to Successful Real-Time Field Management

et al. 2010

View full text Add to dashboard Cite

This paper describes how Brunei Shell Petroleum Co Sdn Bhd (BSP) uses cross validated and reconciled real time production data across large offshore and onshore production networks to support more proactive day-to-day oil and gas production surveillance and management. Examples are presented of the gathering network surveillance systems for the extensive BSP East and Darat Production Assets.In modern oil fields, there is an abundance of instrumentation distributed over often large geographical areas. The production network ranges from the individual wellheads, to production manifolds, test and bulk separators, past surge vessels and export pumps, to crude dehydration tanks at a central crude terminal or to the gas compressors and gas export points. At least the initial parts of the production gathering network at the wells will have multiphase flow with uncertain and variable oil, water and gas proportions. Normally the most downstream flow meters are well calibrated with good calibration records, but the actual accuracy of the majority of the flow meters upstream will be uncertain, and they will not be nominally designed to handle multiphase fluids or mixtures of fluids with varying densities. Conventionally, it is regarded to be problematic to track production variations in real time across the network back to the source wells. This is due to issues with metering multiphase flows and assumed uncertain transport delays.It is shown here that it is now practical to track in real time production rates across large production networks, working back from the most downstream, well metered, points to the individual bulk separator units or production platforms or the wells themselves. Indeed, it is possible to obtain a consistent, real-time reconciled view of the current production rates across these larger production networks. This allows more accurate surveillance of production from the wells, early detection of measurement issues and quicker responses to system upsets. Various common blockers to real time network wide production flow surveillance are addressed, including noisy meters, storage tanks, on-off pumps and hard-to-measure multiphase flows from the wells. The work reported may be seen as a "top-down" approach that complements the existing metering systems, integrating the data to "make the best of" all available metering and instrumentation. An example shows how better metering and instrumentation, virtual metering and real time data analysis are combined to detect and correct significant discrepancies.Raw ultrasonic flow meter signal in black, filtered signal is in red, reconciled filtered signal is in blue.

show abstract

Section: Real Time Surveillance Of East Asset Offshore Production Liqmentioning

confidence: 99%

Asset-Wide Reconciled Production Monitoring—A Key Enabler to Successful Real-Time Field Management

et al. 2010

View full text Add to dashboard Cite

show abstract

Appraisal and Development of Thin Oil Rims Using the Smart Field Approach, An Example from Champion West, Brunei

Bakker¹,

Liew²,

Dale-Pine³

et al. 2009

Asia Pacific Oil and Gas Conference &Amp; Exhibition

View full text Add to dashboard Cite

The economic development of thin oil rims associated with large gas caps in multi-stacked reservoirs presents many challenges. In the structurally complex Champion West field, offshore Brunei, innovative well designs together with detailed subsurface studies have unlocked thin oil rims. Earlier development phases comprised deviated and snake wells with multi-zone smart completions. In some areas these wells have resulted in cross-fault depletion of the remaining smaller oil targets. An appraisal strategy was put in place to address the major uncertainties associated with the smaller targets, such as complex fluid distribution and connectivity to existing producers. This strategy comprised drilling pilot holes from development wells, which were evaluated using advanced mud gas logs, downhole pressure measurements and wireline/ logging whilst drilling (LWD) logs to confirm fluid distribution and understand connectivity. This paper discusses one such example, where production data from smart wells has been incorporated with appraisal data to optimise well design, placement and production from a thin depleted oil rim. Multi-rate test information has been used to adjust down-hole inflow control valve (ICV) settings, initially to balance drawdown along the horizontal wells and later to minimise water and gas cap production. Introduction The Champion West field is situated approximately 90 km offshore Brunei in around 50 m water depth. It is composed of approximately 1200m of vertical reservoir sequence with over twenty five separate pressure cells defined to date with complex and variable fluid distributions. The field comprises a series of NNE- SSW-trending elongated fault-blocks [1]. The oil rims discussed in this paper are located in the structurally less complex outer blocks (53–56) at intermediate depth (P5.0-P7.3: 3000–3200 mtvdss). The reservoirs are dipping 20–26 deg and consist of thin sands (1–5m) with limited vertical communication. The recovery from individual sands is typically insufficient for a dedicated horizontal well and combining sands is therefore a must. Large gas caps and weak to moderate aquifers support the oil rims. The vision is to develop Champion West as a "Smart Field" [2]. This includes unmanned platforms, remotely controlled and operated including surface and downhole chokes. Pressure and temperature readings from surface and downhole gauges and fluid flow data are available real-time in the office and feed data driven models that automate production allocation and suggest choke settings to optimize recovery [5]. The smart snake well is selected as the development concept for many oil targets in the field. A snake well meanders in a horizontal sinusoidal pattern through multiple sands providing multiple drainage points in multiple sands. A typical smart snake completion consists of multiple production zones isolated by swell packers. Each zone is equipped with a downhole choke (ICV) and a dual gauge (P,T annulus and tubing). The development of narrow elongated oil rims requires a long horizontal section. Managing torque and drag is key to successful completion. Smart snakes have been successfully applied in Champion West and have shown several advantages [4]. A brief summary of the field development history is given in the next section. For the development of the smaller oil rims, low cost appraisal sidetracks are drilled from the development wells. This paper discusses one example (CW-G), where the smart snake well concept with appraisal sidetrack is used to develop narrow elongated oil rims.

show abstract

An Evolution From Smart Wells to Smart Fields

Cited by 2 publications

References 0 publications

Asset-Wide Reconciled Production Monitoring—A Key Enabler to Successful Real-Time Field Management

Asset-Wide Reconciled Production Monitoring—A Key Enabler to Successful Real-Time Field Management

Appraisal and Development of Thin Oil Rims Using the Smart Field Approach, An Example from Champion West, Brunei

Contact Info

Product

Resources

About