Maharon Bin Jadid

Temana Field Pilot Implementation : A Shift In Sand Control Philosophy To Improve Well Performance

The Temana field consists of unconsolidated reservoirs which require active sand control. Conventional Internal Gravel Packed (IGP) technique has been widely applied as it has provided a reliable means of abating sand production. These completions however, have shown high skins (>15) which had increase with time due to fines migration into the packed area especially with the advent of water production. In many cases, flow efficiencies were reduced by 70% and this had severely affected well performances with aging.

Fines erosion: Turbophoresis can be harmful

Enabling turbulence dispersion in a computational fluid dynamics simulation of a developing liquid–solid pipe flow leads to a focus of low-Stokes number particles around the pipe axis. This phenomenon is found to concentrate their impacts on a centrally located target surface such that a local erosion spot develops. This result is counter-intuitive as low-Stokes particles are deemed to follow the carrier average streamlines going around the body, which diminishes their probability of impact. This is nevertheless a fact reported experimentally too. Analysis of the simulations reveals that turbulence tends to drive preferentially tiny particles from areas of high to low agitation. This phenomenon is sometimes named as turbophoresis. Long straight piping systems are typical candidates for turbulent pipe flows hosting an annular zone of turbulence that tends to disperse and concentrate fines towards the axis. At the approach of a body, like a cross-flow cylinder, particles may be somewhat re-scattered away by...

The First Subsea Completion by an Operator in KN Field, Offshore Malaysia

The KN field in KM cluster is located approximately 200km offshore, at water depths ranging from 59‐102m. The field is part of the KM Cluster Integrated Development Plan, where the primary objective for KN field development is to recover the reserve from fringing pinnacle reef carbonate reservoir, expected to be achieved through two deviated 7‐inch open‐hole monobore subsea wells. KN field is expected to deliver around 200 to 300 MMSCF/day to the LNG plant to help relieve an anticipated gas shortage, as such failure to deliver the target would definitely upset the gas supply. Besides cost savings, the shallow water subsea development concept is part of the company’s long‐term vision to train its staff with new technologies and prepare them with basic guidelines for future development especially in deepwater. Although this is already considered a norm in other parts of the world, subsea completion is relatively a new experience in the company operation. The open‐hole sections were drilled using Potassium/Sodium formate fluids with calcium carbonate as weighting and bridging agent and later the wells were completed with Cessium formate. Based on extensive laboratory test, it was found that this formate fluids allow for thin mud filter cake that can be remove effectively with differential pressure alone, excluding the need for filter cake breaker. High rate acidizing was planned as contingency should the wells failed to deliver the targeted well deliverabilities. Based on transient simulation using OLGA, high rate clean‐up were planned to ensure effective filter cake break‐up, removing debris and confirming the technical potential of the wells. With high rate, the duration of well clean‐up is shorter and effective thus saving rig time. This paper details the planning and execution towards achieving the successful project of KN field, the 1st subsea development in the company.

First Horizontal Openhole Gravel Pack Installation in a Clastic Gas Reservoir: KM Field

The KM field is part of the KM cluster development project, which plans to deliver 100 MMscf/D of gas to liquefied natural gas (LNG) from five horizontal wells. Four of the wells were completed with 4 1/2-in. production tubing using horizontal openhole gravel packs (HZOHGPs) as sand control, which was the first application of this technology for the operating company. Based on geomechanical modeling, the KM field is an unconsolidated clastic gas reservoir that requires active sand control. The particle size distribution (PSD) suggests that the KM clastic formation is a poorly sorted sand with a high uniformity coefficient and very high fines content; thus, justifying the need to use a gravel pack completion rather than a screen-only completion. The conventional internal gravel packed (IGP) technique has been widely applied because it provides a reliable means of abating sand production. However, it does not provide the same productivity as a HZOHGP. IGP is also highly prone to increasing skin throughout the production life of the well. Nodal analysis indicates that HZOHGP would give the highest production index (PI) with low production drawdown compared to a cased-hole gravel pack completion, in addition to potential cost savings realized from the elimination of the casing, cementation of the casing, and perforation of the casing. Running a screen in conditioned, solids-free mud, avoiding premature bridging during the job execution, proper removal of the mud filter cake, and limiting flow to below critical drawdown pressure (CDP) play important roles in the successful implementation of a HZOHGP completion in the KM field. This paper describes the planning of the first openhole gravel pack installation for an unconsolidated gas formation while highlighting the risk assessment, the lessons learned, and the excellent production performances achieved. Use of OLGA® transient simulators for estimating drawdown during well cleanup is also briefly discussed.

Successful Application of Novel Organic-Solvent-Mud-Acid Stimulation Approach for Unlocking Productions and Optimising Field Watercut in the Temana Offshore Brownfield

One of the key successes in optimising a mature offshore oil producing field with water drive mechanism is to actively unlock additional oil production from reservoirs that have not experienced water breakthrough while maintaining gross production from reservoirs that have started producing water. This can be achieved by drilling more infill wells to create additional oil drainage points; however this is a very capital intensive investment. The other approach is to perform stimulation jobs on existing wells (both idle and producing) as part of production enhancement activities to increase well productivities which are comparatively more cost effective. With the increase in well productivities, these wells can be produced at lower drawdown which can delay water breakthrough. This paper describes a holistic approach from understanding well inflow productivity problem due to severe downhole asphaltene or wax deposition issues, formulating the right organic-solvent-mud-acid chemical recipe for the well stimulation jobs, selecting the appropriate well candidates, and optimizing offshore stimulation job execution to ensure good chance of success. The stimulation campaign for 3 wells was carried out between Dec 2009 and Jan 2010 and was proven to be very successful. The cost per job was reduced by 30% compared to previous stimulation job, oil production for all wells increased (including a well which is closed in for 10 years), and up to date, water production has not been observed. Finally, a post job detailed technical analysis was conducted to allow a better understanding on the chemical recipe performances for optimization of future stimulation jobs.

Improved Frac and Pack Job Design and Execution in Baram Field—A Case History

Baram Delta Field is a mature hydrocarbon-producing field in east Malaysia. The reservoirs are predominantly friable and unconsolidated. Downhole sand-exclusion systems are required to help ensure prolonged well productivity.