Sumpal Field, South Sumatra - case history of the delineation and production of a fractured basement reservoir

Chalik, Mu'adz; Pujasmadi, Bambang; Fauzi, Muhamad; Bazed, Mahmud

doi:10.29118/ipa.314.199.224

Cited by 4 publications

(2 citation statements)

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“…Although they are only about 20% of the total number of oil and gas fields discovered in the South Sumatra Basin, these fields are spread across the basin and provide good coverage for the study. The majority of the data was extracted from the Oil and Gas Fields Atlas of South Sumatra, a 1990 publication from the Indonesian Petroleum Association compiled by Courteney et al Additional information of several fields was added to this database, including Dayung Field (Suyoto & Bethancourt, 2010), Sumpal Field (Chalik et al, 2004), Kaji-Semoga Field (Atkinson & Hutapea., 2006), Makmur Field (Lu et al, 2005) and Betara Northeast Field (Suta & Utomo, 2006), From the structural map the crest, oil-gas contact, oil-water contact, and gas-water contact were extracted. Figure 4 shows the definition of these terms in a structural petroleum trap model.…”

Section: Hydrocarbon Column Datamentioning

confidence: 99%

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Hydrocarbon Columns of Oil and Gas Fields in the South Sumatra Basin

Napitupulu¹,

Jannah²,

Silaen³

et al. 2021

Bsed

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The South Sumatra Basin is a prolific basin with a long history of oil and gas exploration that started in early 1900s. It is located in the southern part of Sumatra Island, Indonesia, where more than 300 oil and gas fields have been discovered. The basin contains multiple hydrocarbon reservoir horizons, from Pre-tertiary Basement to Miocene age. The kitchen areas also have various depths, with different levels of maturity. This petroleum system variation is reflected by the field size distribution and the heights of the hydrocarbon columns.Many authors have discussed the petroleum system of this basin and they are useful for providing regional geological perspectives. The oil and gas fields in South Sumatra are usually discussed independently by the operators. Different seismic vintages, density and quality make seismic correlations across the basin challenging. Apart from that, the data restriction is another hurdle in making correlation of the fields. Therefore, statistical studies of the fields and play level understanding become challenging.This study utilizes the Indonesian Petroleum Association Atlas of South Sumatra oil and gas fields, which was published in 1990. Several new fields, especially in fractured basement reservoirs, were added, based on recent publications. Additional information from the IHSE fields database was used to support the study. These data allow a statistical study on hydrocarbon column heights in the South Sumatra Basin. The result of this study could explain more about the charge and seal elements in the basin.

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Section: Hydrocarbon Column Datamentioning

confidence: 99%

“…The oil and gas fields in South Sumatra are usually discussed independently by the operators (e.g. Carrillat et al, 2013;Chalik et al, 2004;Lu et al, 2005;Suta & Utomo, 2006). Different seismic vintages, density and quality make seismic correlations across the basin challenging.…”

Section: Introductionmentioning

confidence: 99%

Hydrocarbon Columns of Oil and Gas Fields in the South Sumatra Basin

Napitupulu¹,

Jannah²,

Silaen³

et al. 2021

Bsed

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Development Well Drilling with Sacrificial Drill Pipe Completion in Fracture Basement Reservoir: Case Study from a Field in Corridor Block, South Sumatra Basin Indonesia

Permana

Darmadi

Hamid

et al. 2020

SPE/IATMI Asia Pacific Oil &Amp; Gas Conference and Exhibition

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X gas field is located in the Corridor block of Onshore South Sumatra, Indonesia and operated by ConocoPhillips Grissik Ltd. (CPGL). The field was first discovered in 1994 and started production in 2001. In terms of reserves, X field is the second largest in the Corridor. All production comes from fractured igneous (granite, granodiorite) and metamorphic (meta conglomerate, quartzite, phyllite and marble) rocks of the pre-Tertiary basement. To date, eight wells have been drilled during the exploration and development program. The most recent development well was the X-8, which was drilled in 2017. The X-8 well was designed to enter the top of the reservoir structure at a location where the seismic amplitude exhibited dimming. Based on analysis of the seismic and well productivity, dimming amplitudes are indicative of faults and fractures. Historically, exploration, appraisal and development wells drilled in the field did not experience any wellbore stability issues. During drilling of the X-8, wellbore stability and collapse caused significant problems and resulted in the sidetracking of the well three times. Prior to the drilling, it was recognized that depleted reservoir conditions may result in wellbore stability issues, but the rock strength was determined to be sufficient to overcome any wellbore collapse. It would only be necessary to overcome the pressure difference, and this could be done using managed pressure drilling (MPD). Although MPD was implemented successfully, the wellbore collapsed during drilling and before the completion string could be run. Ultimately, the well was completed using the drill string since standard completions were impossible under the time constaints. An after-action review of X-8 was conducted, and hypotheses were generated to explain the wellbore stability issue in this well. The review included fault interpretation uncertainty, lithology competency, reservoir lithology and geomechanics. Based on this work, two explanations were suggested as the main cause of wellbore collapse. The first explanation is that the top of the basement consists of a weathered zone resulting from exhumation in the Mesozoic. The weathered zone consists of rock material generated by both physical and chemical weathering. The second explanation is shear failure due to reservoir depletion. Both explanations are supported by well data, seismic attributes and current reservoir pressure. In the end, with an understanding of the potential failure mechanism, the last sidetrack was completed by leaving the drill string inside the hole to enable the well to produce. The learnings suggest that drilling through fracture basement reservoir is challenging and with depletion, the reservoirs can be nearly impossible to drill. Casing or liner drilling may be the only solution to successfully drill these types of wells and produce the hydrocarbons.

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A Unique Completion Design Using Perforated Drill Pipe in the Onshore Southern Sumatra Basin

Tejo

Singamshetty

Tupamahu

et al. 2020

SPE/IATMI Asia Pacific Oil &Amp; Gas Conference and Exhibition

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An operator recently drilled and completed an onshore well in South Sumatra by intentionally leaving 3-1/2 in. drill pipe in the hole, to be used as the lower completion string. This paper documents the design and execution of this unique drill pipe completion idea, overcoming challenges during drilling due to unanticipated formation collapse, leading to multiple sidetracks. The reservoir contains dry gas with >30% CO2 inside naturally fractured basement rock. Wells in this area are usually drilled with total losses throughout the reservoir section and completed by running a perforated liner. In the 3rd and final sidetrack, the drill pipe completion idea was successfully executed resulting in a well that is producing ∼40 MMSCFD. The idea was selected after technically evaluating other viable options such as liner drilling using 5-1/2 in. casing or drilling with continuous water injection and then running the liner. The drill pipe completion option provided the highest chance of success to reach total depth (TD) in a single bit run while serving as a mechanical conduit in the wellbore for production and providing a barrier against hole collapse. The detailed planning conducted to finalize the drilling bottom hole assembly (BHA), perforating gun performance, drill pipe cutter, production rate impact, erosional and corrosion impact of using drill pipe as completion will be explained in the paper. Operationally, after the well was drilled to TD, 1-11/16 in. strip guns were used to perforate the 3-1/2 in. drill pipe and then the pipe was severed using a non-explosive plasma jet cutter and left in hole. A fishing overshot was then run on the bottom of lower completion liner to swallow the cut drill pipe and provide future intervention capability. The upper completion was subsequently run and set prior to rig demobilization. This unique application of a sacrificial drill pipe completion, also termed as the "crazy drill pipe idea" by the operator, generated a lot of discussion and interest within the oil and gas industry in Indonesia. We are hopeful that the technique and application discussed in this paper will provide valuable insight into this alternative completion design for use in depleted and unstable formations, where opportunities to pursue other viable options are limited.

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Sumpal Field, South Sumatra - case history of the delineation and production of a fractured basement reservoir

Cited by 4 publications

References 0 publications

Hydrocarbon Columns of Oil and Gas Fields in the South Sumatra Basin

Hydrocarbon Columns of Oil and Gas Fields in the South Sumatra Basin

Development Well Drilling with Sacrificial Drill Pipe Completion in Fracture Basement Reservoir: Case Study from a Field in Corridor Block, South Sumatra Basin Indonesia

A Unique Completion Design Using Perforated Drill Pipe in the Onshore Southern Sumatra Basin

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