Geochemistry and petrology of selected coal samples from Sumatra, Kalimantan, Sulawesi, and Papua, Indonesia

https://espace.library.uq.edu.au/view/UQ:347477/UQ347477_OA.pdf

Temporal changes in microbial community composition during culture enrichment experiments with Indonesian Coals

Preliminary investigation of biogenic gas production in Indonesian low rank coals and implications for a renewable energy source

The production of methane from wet coalbeds is often associated with the production of significant amounts of water. While producing water is necessary to desorb the methane from the coal, the damage from the drilling fluids used is difficult to assess, because the gas production follows weeks to months after the well is drilled. Commonly asked questions include the following: What are the important parameters for drilling an organic reservoir rock that is both the source and the trap for the methane? Has the drilling fluid affected the gas production? Are the cleats plugged? Does the 'filtercake' have an impact on the flow of water and gas? Are stimulation techniques compatible with the drilling fluids used? This paper describes the development of a unique drilling fluid to drill coalbed methane wells with a special emphasis on horizontal applications. The fluid design incorporates products to match the delicate surface chemistry on the coal, a matting system to provide both borehole stability and minimize fluid losses to the cleats, and a breaker method of removing the matting system once drilling is completed. This paper also discusses how coal geology impacts drilling planning, drilling practices, the choice of drilling fluid, and completion/stimulation techniquesmore » for Upper Cretaceous Mannville-type coals drilled within the Western Canadian Sedimentary Basin. A focus on horizontal coalbed methane (CBM) wells is presented. Field results from three horizontal wells are discussed, two of which were drilled with the new drilling fluid system. The wells demonstrated exceptional stability in coal for lengths to 1000 m, controlled drilling rates and ease of running slotted liners. Methods for, and results of, placing the breaker in the horizontal wells are covered in depth.« less

State-of-the-Art in Coalbed Methane Drilling Fluids

The production of methane from wet coalbeds is often associated with the production of significant amounts of water. While producing water is necessary to desorb the methane from the coal, the damage from the drilling fluids used is difficult to assess, because the gas production follows weeks to months after the well is drilled. Commonly asked questions include the following: • What are the important parameters for drilling an organic reservoir rock that is both the source and the trap for the methane? • Has the drilling fluid affected the gas production? • Are the cleats plugged? • Does the “filtercake” have an impact on the flow of water and gas? • Are stimulation techniques compatible with the drilling fluids used? This paper describes the development of a unique drilling fluid to drill coalbed methane wells with a special emphasis on horizontal applications. The fluid design incorporates products to match the delicate surface chemistry on the coal, a matting system to provide both borehole stability and minimize fluid losses to the cleats, and a breaker method of removing the matting system once drilling is completed. This paper also discusses how coal geology impacts drilling planning, drilling practices, the choice of drilling fluid, and completion/stimulation techniques for Upper Cretaceous Mannville-type coals drilled within the Western Canadian Sedimentary Basin. A focus on horizontal coalbed methane (CBM) wells is presented. Field results from three horizontal wells are discussed, two of which were drilled with the new drilling fluid system. The wells demonstrated exceptional stability in coal for lengths to 1000 m, controlled drilling rates and ease of running slotted liners. Methods for, and results of, placing the breaker in the horizontal wells are covered in depth.

/pdf/state-of-the-art-in-coalbed-methane-drilling-fluids-2gg2c1kruk.pdf

Indonesia has thick, low-rank coal deposits that are prospective for coalbed methane (CBM) development but remain untested. Conventional oil and gas wells that drill through these coal seams experience gas kicks and blow outs, good CBM indicators. We analyzed petroleum and coal mining data to perform a comprehensive assessment of Indonesia’s CBM resources. We identified 12.7 trillion m (450 Tcf) of prospective CBM resources within eleven onshore coal basins. Full-cycle development costs in highgraded areas are estimated at $0.70/Mcf. These potential CBM reservoirs could be tested at low cost using coreholes or production “wells of opportunity.” Introduction Coalbed methane (CBM), which is methane desorbed and produced from deep coal seams, has become a significant source of natural gas supply in the USA. From humble beginnings in the 1980’s, CBM production has steadily grown to the current 127 million m/day (4.5 Bcfd), nearly 10% of total USA natural gas production. CBM reserves at the end of 2002 stood at 18.5 Tcf. Cumulative reserve additions, including past production, total nearly 30 Tcf. Much of this reserve is low-cost natural gas with all-in supply costs of under $1.00/Mcf. Outside the USA, CBM is undergoing initial commercial development in Australia and Canada, while exploration is underway in China, India, South Africa and several other coal-rich countries. Indonesia has extensive coal deposits distributed in eleven onshore coal basins (Figure 1), yet has not yet experienced significant CBM testing [1]. There has been a perception by CBM operators that Indonesia’s coal deposits are too shallow and too low rank to be prospective. After all, Indonesia’s coal mining sector produces primarily lignite or sub-bituminous coal from open-pit mines that have no significant methane control issues. However, this perception is changing due to several factors: a) The success of low-rank CBM development in the Powder River Basin, Wyoming, USA, where gas production is more than 28 million m/day (1.0 Bcfd) and increasing rapidly; b) improved understanding that the shallow coal seams mined at the surface in Indonesia dip basinward and become gas charged at CBM target depths (100-1,500 m) over broad areas; and c) strong and nearly ubiquitous gas kicks that are recorded on petroleum well mud logs as these deep coal seams are penetrated, sometimes causing hole stability problems, and indicating that the coals have adsorbed large quantities of methane. This study was supported by the Asian Development Bank and Indonesia’s Department of Energy and Mineral Resources (MIGAS). It builds on earlier data compilation efforts supported by PT Caltex Pacific Indonesia and Pertamina [2,3] and laboratory work performed by the Indonesian Ministry of Energy and Mineral Resources [4]. A separate component of the project, not discussed here, involved assisting MIGAS in formulating regulations for commercial CBM investment and development. Data Control Extensive surface and subsurface data are available in Indonesia for basic CBM parameters such as coal thickness, depth, rank and other coal properties. We assembled a GIS data base of these coal properties acquired from coal exploration coreholes, deep petroleum exploration well logs, measured coal outcrop sections, and laboratory data such as vitrinite reflectance and volatile matter analyses. Recently, adsorption isotherms have been run on a handful of coal samples, which remain confidential. Other data on CBMspecific reservoir properties remain scarce or non-existent. Coal seam permeability has not yet been tested in situ using well testing. No CBM production wells have been tested to date, nor has hydraulic fracturing of coal seams been attempted. Despite this paucity of data, it is still possible to make rough estimates of in-place CBM resource distribution and potential producibility. Basin characteristics are summarized in Table 1. SPE 88630 Indonesia: Coalbed Methane Indicators and Basin Evaluation Scott H. Stevens, Advanced Resources International, Inc., SPE Hadiyanto, Indonesian Ministry of Energy and Mineral Resources, Directorate General of Geology and Mineral Resources

Indonesia: Coalbed Methane Indicators and Basin Evaluation

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Indonesia: Coalbed Methane Indicators and Basin Evaluation