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Collaborating Authors
Post Rift Oligocene Marine Source Rock, a New Petroleum System in Greater Bangkanai, Upper Kutai, Indonesia
Nugroho, Bayu (Ophir Energy Indonesia) | Guritno, Elly (Ophir Energy Indonesia) | Mustapha, Haryo (Ophir Energy Indonesia) | Darmawan, Windi (Ophir Energy Indonesia) | Subekti, Ari (Ophir Energy Indonesia) | Davis, Carey (Ophir Energy Indonesia)
Abstract The long-held view and general understanding on the source rock within the Upper Kutai Basin is that it comes from the fluvial-deltaic facies. This deltaic coals and carbonaceous source rock has been proven generating gas with oil in Western Indonesian tertiary basins such as the Miocene Balikpapan Formation in the Lower Kutai Basin, Tanjung Formation in the Barito Basin and TalangAkar Formation in the South Sumatra Basin. The Oligocene carbonate play in the Upper Kutai Basin is under-explored, with exploration historically focusing on the Miocene deltaic and turbidite plays. These carbonates mainly consist of the UjohBilang or Berai equivalent Formation which outcrops along the southern and western margin of the basin, and is seismically imaged in the subsurface, forming on isolated basement highs and large platform areas. Ophir Energy's Kerendan Gas Field in the Bangkanai PSC is the only Oligocene carbonate gas producer in the Kutai Basin. Development drilling on the Kerendan Field and the West Kerendan-1 exploration well has provided new information which, together with a re-evaluation of the existing carbon isotope and other geochemical data has led to a reinterpretation of the source rocks for Kerendan gas. The gas was previously postulated to be generated from Eocene terrestrial source rocks similar to the source rocks that generated oil and gas in the neighboring Tanjung Field in the Barito Basin, 100 kms to the South. The recent carbon isotope data from the Kerendan wells reveals that the gas in the Oligocene carbonate reservoir in Kerendan was generated from a marine source rock and is not terrestrial in origin. In addition there is also a terrestrial component within the gas found at the younger stratigraphic interval.
- Asia > Indonesia > East Kalimantan > Makassar Strait (0.90)
- Asia > Indonesia > Kalimantan > Central Kalimantan > North Barito (0.57)
- Phanerozoic > Cenozoic > Paleogene > Oligocene (1.00)
- Phanerozoic > Cenozoic > Neogene > Miocene (1.00)
- Geology > Rock Type > Sedimentary Rock (1.00)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (1.00)
- Geology > Sedimentary Geology > Depositional Environment > Transitional Environment > Deltaic Environment (0.66)
- Asia > Indonesia > Sumatra > South Sumatra > South Sumatra Basin (0.99)
- Asia > Indonesia > Kalimantan > Upper Berai Formation (0.99)
- Asia > Indonesia > Kalimantan > Berai Formation > West Kerendan-1 Well (0.99)
- (4 more...)
Abstract This paper reviews applications of hydrajet perforating during the past 6+ years specifically as they apply to horizontal and highly deviated completions for both oil and gas reservoirs. Many benefits to hydraulic fracturing through hydrajetted perfs instead of shape charge perforations will often exist. Also, a key feature to more economic applications has been coupling this process with a method that includes multi-stage fracturing operations. This feature can shorten the completion time needed to achieve multistage frac treatments. During this decade, horizontal wells that need fracture stimulation are being drilled deeper and, especially, with longer lateral sections requiring larger numbers of fracturing stages. This has increasingly challenged the limits of conventional jetting systems and methods, while requiring higher pressure limits for the wellhead, treatment tubing, and pumping equipment. Three primary methods for using hydrajet perforating have been part of the surge of horizontal well applications. Listed in the order of their emergence of significant application during the present decade, they are: hydrajet fracturing (HJF), hydrajet perforating, annulus path fracturing (HPAP), and standalone use of hydrajetted perforating (SHJP) followed by conventional wellbore stimulation and isolation applications. Introduction Hydrajetting technology has been in use in various industries since the early 1960s (Summers 1995). In the oil industry, hydrajetting predates even the 1960s with downhole applications such as hydrajetting in openhole sections of wellbores, sometimes using acid in carbonate formations. Additionally, it has been used in removal of scale or other deposits, wellhead removal, decommissioning of offshore rig platforms, and general tubing or casing cutoff applications. One of the more newsworthy applications was the highly successful use of hydrajet equipment in removing burning wellheads in war-torn areas of the Middle East. For the 40+ years before this decade, however, most hydrajetting in downhole oilfield applications had been used only when other technologies had failed; most often when formation breakdown could not be achieved through conventional shape-charge perforations. Until recent years, hydrajetting was generally much more complicated, more costly, and more pumping equipment intensive than conventional methods, but its unique value was occasionally demonstrated in perforating for well production and stimulation (Surjaatmadja 1993, Surjaatmadja et al. 1994). The first process that combined hydrajet perforating with a new invention, hydrajet assisted fracturing, occurred in the late 1990s. This new fracture stimulation process offered features and advantages that created opportunities for controlled, multistage fracture stimulation of lateral completions that did not have cemented liners. The simultaneous deployment of hydrajet perforating with hydrajet-assisted fracturing (HJF) makes the process both effective and economical (Surjaatmadja 1998, Surjaatmadja et al. 1998). The method is most suited for horizontal applications, where frac gradients will be reasonably similar at most locations along the lateral section that stays within a single formation. There are generally no methods of mechanical sealing incorporated, relying instead on the highly localized and intense focus of dynamic fluid force (and Bernoulli effects) such that, for each fracturing stage, it will first force fracture initiation at the targeted point and continue to only extend a facture at the jetting-tool location. The multistage process must start at the frac location closest to the toe and sequentially progress toward the heel.
- North America > United States > Texas (1.00)
- North America > Canada (0.93)
- Asia (0.88)
- Europe (0.67)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type (0.69)
- North America > United States > Texas > Haynesville Shale Formation (0.99)
- North America > United States > Louisiana > Haynesville Shale Formation (0.99)
- North America > United States > California > San Joaquin Basin > Lost Hills Field (0.99)
- (2 more...)
Abstract As oil and gas reserves are declining, operators all over the world are now being forced to go to land areas with extreme conditions and deeper into the sea to find more reserves. The reservoirs are getting more complex and well designs are becoming more complicated and costly. The complex reservoirs and extreme conditions require several individual zones to be completed and fractured individually to access maximum reservoir and get the biggest return for the money. Oftentimes, each zone requires a specifically designed fracturing treatment to effectively treat it. A lot of money and time are lost each year when operators try to treat these multizones using conventional techniques. The optimum production rates are not achieved and the reservoir-recovery factor is low, leaving most of the oil and gas unrecovered. Because of the recent drop in oil and gas prices, cost, time, and production are the driving factors causing operators to look for alternate completion and fracturing methods to reduce cost and time without compromising production. Numerous techniques and hit-and-trial methods have been tried throughout the past decade to overcome this problem. Multistage fracturing has offered one of the best solutions to everyone in this tough economic environment. Throughout the past few years, there has been a growing acceptance among both operators and service companies that hydra jet (abrasive jetting) perforating can improve overall well economics for fracture-stimulated wells in many reservoirs. More and more customers all over the world are now using multistage fracturing to access the complex reservoirs and treat wells with complex completions. In a few cases, pinpoint stimulation has proven to be the only way that effective stimulation could be achieved. The pinpoint-stimulation portfolio has evolved throughout the past decade to offer several options to different well conditions and types. This paper presents a detailed review of many pinpoint-stimulation technologies that have been successfully used for treating multizones in complex reservoirs and extreme well conditions in the last decade, either in new wells or in mature fields, to improve the production and reservoir recovery factor. It provides insight to strategies of how these different technologies were applied to different well conditions. Case histories are provided to support the obtained benefits and advantages, and lessons learned are discussed along with recommendations and what to avoid in field operations. Future directions of pinpoint stimulation are also discussed. Multistage fracturing can be performed in different ways, depending on the well design and completions. More and more customers are now designing the well and selecting completions based on the multistage fracturing technique that best accesses the reservoir efficiently. The following multistage fracturing techniques are discussed in this paper: CT applications. Jointed-pipe applications. Sleeve applications. Perf-and-plug applications. Globally, pinpoint-stimulation treatments have been performed on more than 6,000 wells in 18 countries. Multistage fracturing is gaining popularity in the oilfield industry with each successful treatment that is put into the ground. With the use of CT, the task of placing many cuts at multiple places is straightforward and not time consuming. For many wells needing multistage fracture stimulations, significant reductions in nonproductive time (NPT) help reduce well costs, even when more actual fracture stages are pumped. The use of more stages has often provided significant production gains and greater recoverable reserves. In this paper, different techniques for a wide variety of applications and a review of successful evolution of multistage fracturing in the last decade are presented.
- South America > Brazil (1.00)
- North America > United States > Texas (1.00)
- North America > United States > Oklahoma (1.00)
- (5 more...)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.69)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play (0.46)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Garoupa Cluster > Congro Field (0.99)
- South America > Argentina > Patagonia > Neuquรฉn > Neuquen Basin (0.99)
- Oceania > Australia > South Australia > Cooper Basin (0.99)
- (30 more...)
Horizontal Well Completion and Stimulation Techniques--A Review With Emphasis on Low-Permeability Carbonates
Rodrigues, Valdo Ferreira (Petroleos Brasileiro S.A.) | Neumann, Luis Fernando (Petrobras S.A.) | Torres, Daniel Santos (Halliburton Energy Services Group) | Guimaraes De Carvalho, Cesar Roberto (Schlumberger) | Torres, Ricardo Sadovski (BJ Services Do Brasil Ltda.)
Abstract This paper presents a brief review of the available techniques in the oil and gas industry to complete and stimulate horizontal wells, with emphasis on low permeability carbonates. These techniques can also be applied in non-conventional reservoirs, particularly in tight formations. The paper starts by reviewing the lessons learned in some chalk fields in the North Sea (Dan, Halfdan, South Arne, Valhall and Eldfisk) and in a few pilot projects offshore Brazil (Congro and Enchova). Based on these lessons learned and in the broad literature, the paper devises some considerations on the methodology to select completion and stimulation techniques for horizontal wells. Cased and cemented horizontal wells, in addition to open hole and perforated/slotted liners wells are addressed. The macro aspects of field/area management are stressed as the completion and stimulation drivers. The key parameters for designing, implementing and evaluating horizontal completion and stimulation are presented, emphasizing the most common failures and the controversial aspects. The paper presents a summary of mature field and new scenarios that are candidate to horizontal completion and stimulation in Brazil and other Latin America countries. Then it makes a few comments on the resources available in Latin America to face the mentioned opportunities and related challenges. It is supposed that this brief review will be useful for the low permeability scenarios in Latin America and worldwide. Introduction This paper presents a brief review of the available techniques in the industry to complete and stimulate horizontal wells, with emphasis on low permeability carbonates. The emphasis on low permeability carbonates in this work is justified by the renewed importance of this scenario in Brazil and other Latin America countries. Although it does not focus on nonconventional reservoirs, such as tight gas, it is related to them as stimulated horizontal completions have been used on their development. This paper focuses fracturing stimulations, also making a few references to matrix stimulation. It also assumes that a horizontal well has already been justified and what is being discussed is its completion and stimulation. The paper starts by reviewing the lessons learned in some chalk fields in the North Sea (Dan, Halfdan, South Arne, Valhall and Eldfisk) and in a few pilot projects offshore Brazil (Congro and Enchova). Then it devises some thought on the methodology used to select completion and stimulation techniques for horizontal wells. It address cased and cemented horizontal wells, in addition to open hole and perforated/slotted liners completions. The key parameters for designing, applying and evaluating horizontal completion and stimulation are presented, underlining the most common failures and the controversial aspects. Completion and Stimulation of North Sea Low-Permeability Carbonates The North Sea low permeability chalks are taken here as a reference due to the outstanding technological evolution verified there in the last decades. Amongst more than ten fields producing from these reservoirs in the North Sea this paper focuses on the Dan, Halfdan, South Arne, Valhall and Eldfisk fields. The main characteristics of these fields are: shallow waters (43 to 69 m), dry completion, high volumes of OOIP (1.6 to 2.9 billions barrel), low permeability carbonates (0.2 md to 10 md) with microfractures in the central areas (10 md to 120 md), high porosities (up to 48%), soft to very soft chalks, small to medium net pays (15 m to 65 m), high oil saturation (up to 97%), and light oils (about 36o API). What most distinguishes these fields is their over-pressured soft chalks which are subjected to a high degree of compaction under pore pressure depletion, resulting in loss of drilling fluids, rapid production decline, well failures and seafloor subsidence. On the other hand the positive effects of rock compaction as a reservoir drive energy, outweigh by far the negative ones. The recovery factor under primary recovery can be as high as 30%. In general the North Sea chalks experienced an evolution from vertical/directional wells stimulated with acid treatments to multiple fractured horizontal wells.
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean (1.00)
- Europe > United Kingdom > North Sea (1.00)
- Europe > Norway > North Sea (1.00)
- (2 more...)
- Overview (1.00)
- Research Report (0.93)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock (0.86)
- Geophysics > Borehole Geophysics (0.93)
- Geophysics > Seismic Surveying > Passive Seismic Surveying > Microseismic Surveying (0.67)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Garoupa Cluster > Congro Field (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Enchova Cluster > Enchova Field (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Enchova Cluster > Bonito Field (0.99)
- (46 more...)
Abstract As shown by technical papers as early as the 1960s, our industry has long known that hydrajetting perforations or slots through cemented casing could often "bail-out" a problem well that otherwise seemed completely resistant to hydraulic fracturing attempts. For most of the first 50 years of fracturing applications, few operators had sufficient demand for the fracturing process to make it a commodity service, especially before the advent of coiled tubing (CT) services in the 1980s. Often, this type of well service was costly because of the need for both abrasive mixing and high-pressure pumping. In many cases, it was too time consuming to be practical as an "every-well" application, and lower-cost conventional explosive shape-charge perforating seemed sufficient for most wells. As oil and gas prices have drastically increased in recent years, many operators have realized that for some well conditions, the use of hydrajet perforating (HP) can improve fracture stimulation efficiency and well economics. In a few cases HP has proven to be the only way that effective fracture stimulation could be achieved. In the past few years there has been a growing acceptance among both operators and service companies that hydrajet (abrasive jetting) perforating can improve overall well economics for fracture stimulated wells in many reservoirs. Some newer methodologies have combined hydrajet perforating and hydraulic fracturing into a single, continuous, multi-stage stimulation method. For many wells needing multiple fracture stimulations, significant reductions in nonproductive time (NPT) allows for reduced well costs even when more actual fracture stages are pumped. Use of more stages has often provided significant production gains and greater recoverable reserves. Enhanced stimulation success in many moderately hard and very hard formations have proven the value of converting from shape charge perforating to hydrajetting as a stand-alone operation to avoid severe near-wellbore problems during hydraulic fracturing stimulation treatments. Since about 2000, and especially during the most recent 5 years, service providers have progressively expanded the processes, which included hydrajet perforating, especially in conjunction with hydraulic fracturing methods. This paper will review the expanding applications of hydrajet perforating in recent years, including case histories from several global applications. Background Early technical papers tell us that hydrjetting (w/o abrasives) was used with acidizing and fracture acidizing as early as 1939, primarily in zones completed open hole. However, with the incorporation of solid abrasives (hydrjetting, using abrasives) the jetting nozzles in use then could only perform for minutes before excessive erosion became a problem. The literature also reveals that around 1958 there was a renewed interest in sand-jetting and more abrasion-resistant carbide jets were developed. In May, 1961, the Journal of Petroleum Technology included three landmark publications that presented much of what had been happening since 1958 with respect to HP applications, and described other hydrajetting wellbore functions such as jetting cement from casing, cutting casing, scale removal, and other applications. The more extensive of these publications (Brown et al. 1961, and Pittman et al. 1961) had first been presented at technical conferences in October, 1960. The shorter, introductory article (Ousterhout 1961) indicated that by early in 1961 over 5,000 hydrajetting jobs had been performed with a success rate in excess of 90%; more than half of these were perforating applications. At that time, explosive/shape charge perforating was still in its infancy, with bullet perforating still common.
- North America > United States > Louisiana (1.00)
- Europe (1.00)
- Asia (0.93)
- (3 more...)
- Geology > Rock Type > Sedimentary Rock (0.69)
- Geology > Geological Subdiscipline > Geomechanics (0.68)
- South America > Brazil > Campos Basin (0.99)
- Oceania > Australia > South Australia > Cooper Basin (0.99)
- Oceania > Australia > Queensland > Cooper Basin (0.99)
- (8 more...)