Success Story of Sustaining Production of Shallow Sand Reservoir with Screenless Fracpack Treatment in Mangunjaya Field
- Andretiana Putranti (PT Halliburton Indonesia) | I Putu Yudis (PT Halliburton Indonesia) | Sakti Lail Nasution (PT Halliburton Indonesia) | Rio Wijaya (formerly with PT Halliburton Indonesia) | Mohammad Zuly Giansyah (Pertamina E&P Asset 1) | ArdhitoWirawan Sarwono (Pertamina E&P Asset 1) | Erwin Dicky Dusyanto (Pertamina E&P Asset 1)
- Document ID
- Society of Petroleum Engineers
- SPE/IATMI Asia Pacific Oil & Gas Conference and Exhibition, 29-31 October, Bali, Indonesia
- Publication Date
- Document Type
- Conference Paper
- 2019. Society of Petroleum Engineers
- Resin System Flowback Control, Production Optimization, Palembang Sand Formation, Shallow Sand Reservoir, Screenless FracPack
- 1 in the last 30 days
- 107 since 2007
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The wells in Mangunjaya field are known for high basic sediment (BS) production (more than 0.5%) and the need for frequent well interventions to cleanout formation sand production. A Screenless Fracpack operation was recommended as a solution for optimizing oil production by means of either the lifetime of the well or the maximum tolerance of BS% to reduce well intervention costs.
Four of the producing oil wells in the Mangunjaya field were treated with Screenless Fracpack treatment in 2018 as part of a well production maintenance process. This was not only to sustain oil production with the least possible intervention, but to reduce the basic sediment percentage to the range of 0.2 to 0.3% where it could be effectively lifted by beam pump and/or PCP pump.
The wells were producing from the Palembang Sand Formation with a total perforation interval of 3 - 17 m per well. The bottomhole pressure and temperature of the Palembang Sand Formation were 257 - 301 psi and 108.5 - 121°F. This formation is a shallow sand with the depth of the formation of 200 - 350 meters (TVD) and the formation has good permeability reservoir in the range of 50 - 300 mD.
The job size of the Screenless Fracpack was 30.3 to 37.7 Klbs (34.4 Klbs average) with a resin concentration of 3.75 gal per 1,000 lbm of ceramic proppant. The pumping rate was 12 to 16 bbl/min with surface pumping pressure of 500 to 1,000 psi. The wells were shut-in for 1 – 2 days to let the gel break and to let the resin cure.
Before the Screenless Fracpack treatment, the well production lifetime was around 90 days with two times well intervention with hoist (to cleanout the sand and repair the pump), the wells were producing 20 - 55 BOPD with more than 0.5% BS average. After the Screenless Fracpack treatment, the production lifetime increased. The wells were producing for more than 120 days with zero well intervention and production increased from 61 to 95 BOPD with 0.2 to 0.3 BS% lifted at higher rev/min of beam pump or PCP pump. This means that oil production was increased by 11 to 375% while the BS% was decreased by 33 to 93%.
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Krismartopo, B.D.K.,Notman, L.,Kritzler, T.et al. 2005. A Fracture Treatment Design Optimization Process to Increase Production and Control Proppant Flow-Back for Low-Temperature, Low Pressured Reservoirs. Presented at the SPE Asia Pacific Oil and Gas Conference and Exhibition, Jakarta, Indonesia, 5-7 April. SPE-93168-MS. https://doi.org/10.2118/93168-MS.
Tiffin, D.L.,King, G.E.,Larese, R.E.et al. 1998. New Criteria for Gravel and Screen Selection for Sand Control. Presented at the SPE Formation Damage Control Conference, Lafayette, Louisiana,18-19 February. SPE-39437-MS. https://doi.org/10.2118/39437-MS.