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78 巻, 6 号
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講演
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村田 澄彦, 芦田 彬久, 高橋 悟, 岡部 博2013 年 78 巻 6 号 p. 445-454
発行日: 2013年
公開日: 2015/04/03
ジャーナル フリーIn-depth profile modification, that is blocking the already swept high permeable zones in a reservoir with a gelling agent, would be one of the most effective sweep efficiency improvement (SEI) methods.
Firstly, in this paper, gelling agents developed for the in-depth profile modification are reviewed in order to understand their present situation and problems. Then, it is shown that TAP (thermally active polymer), PPG (preformed particle gel), CDG (colloidal dispersion gel) are suitable for the in-depth profile modification and overcome the difficulties of in-situ gelation, but they still have limitations in the applicable range of pH, temperature, pore throat diameter, and so on.
Secondly, a visualization experiment of the in-depth profile modification performed to a multilayered reservoir model, in which high permeable formations and low permeable formations are alternate, is shown to confirm the effect of indepth profile modification on SEI and oil recovery. Moreover, the problem that the injected water bypasses the blocked zones in high permeable formation from the low permeable formations and the 100% of sweep efficiency is quite difficult to be achieved is shown.
Finally, following results of the numerical simulations conducted to thirty-two heterogeneous reservoir models under the several blocking conditions are shown. The effect of in-depth profile modification on SEI increases with the increase in the volume of gelling agent and the decrease in the volume of chase water. But, in this case, the bottom-hole pressure increases and the risk to cause a severe formation damage or to make a fracture increases. Furthermore, the effect of in-depth profile modification on SEI increases with the increase in the vertical heterogeneity, and the horizontal heterogeneity is less correlated to the effect than the vertical heterogeneity when the heterogeneity indexes, Dykstra-Parsons coefficient and correlation length, are in the range set for this study.抄録全体を表示PDF形式でダウンロード (1744K) -
～「その他のEOR」からの脱却を目指して～菅井 裕一2013 年 78 巻 6 号 p. 455-462
発行日: 2013年
公開日: 2015/04/03
ジャーナル フリーMicrobial EOR (MEOR) is generally understood as one of other EOR techniques although its high potential has been shown through numerous investigations for almost 90 years. The author concludes that the following three challenges should be needed to develop MEOR to a practical EOR.
· Screening for potential microorganisms that can grow under reservoir conditions such as high temperature and high salinity
· Development of commercial MEOR simulator
· Developing real-time sensing system to monitor the target microorganism in reservoir
The author has isolated successfully a thermophilic anaerobe that can degrade long-chain hydrocarbon of crude oil selectively and reduce oil viscosity to 60 percent of its original viscosity after a few days' incubation. It can grow even under a temperature of 80°C and a salinity of 90 g/L. The potential of MEOR using this anaerobe was shown through core-flood experiments.
The author has developed a prototype numerical simulator for MEOR that consists of 5 compositions: degraded oil, undegraded oil, brine, oil-degrading anaerobe, and yeast extract. The growth of the anaerobe depends on the concentration of yeast extract, temperature, and salinity on this numerical model. According to the numerical experiments, growth of the anaerobe and reduction of oil viscosity were found only around the injection well because the anaerobe consumed whole yeast extract around there. Therefore, the recovery factor can be increased by increasing the amount of yeast extract injected.
The author is estimating a possibility of a novel real-time sensing system based on the flow cytometry in order to monitor the target microorganism in reservoir. A target microorganism could be found selectively in culture solution where the target and nontarget microorganisms mixedly exist using a commercial flow cytometer, therefore, the possibility of the sensing system based on the flow cytometry was shown.抄録全体を表示PDF形式でダウンロード (1352K) -
河原 洋平, 髙木 睦人, チュエン グエン チュ, 畠山 厚志, 西﨑 愛子2013 年 78 巻 6 号 p. 463-468
発行日: 2013年
公開日: 2015/04/03
ジャーナル フリーThe Lower Miocene sandstone reservoir in Rang Dong Field, within Block 15-2 offshore Vietnam, has continuous oil production since 1998. Since achieving peak rates in 2002, oil production has steadily declined despite efforts to improve oil recovery. Numerous production improvement techniques were studied with focus on the potential applications of hydrocarbon gas enhanced oil recovery (HCG-EOR). Initial feasibility studies on HCG-EOR indicated potential applicability to addressing the production decline.
The HCG-EOR Pilot Test program, designed with appropriate monitoring plan, was implemented in 2011 coupled with a water-alternating-gas (WAG) scheme. The HCG-EOR pilot test yielded positive EOR impacts such as oil rate increase and water cut reductions concurrently with oil property changes. Reservoir saturation logging on a well between an injector and a producer indicated reduction in residual oil saturation, which is encouraged by injected gas encroachments, in multiple layers. These observations are considered positive indications of the effectiveness of HCG-EOR in a field scale application.
This paper presents the initial feasibility study results, the field findings to date of the HCG-EOR Pilot Test including designs, monitoring plan, results, and the post evaluation toward achieving the HCG-EOR full field scale implementation.抄録全体を表示PDF形式でダウンロード (1890K) -
栗原 正典2013 年 78 巻 6 号 p. 469-481
発行日: 2013年
公開日: 2015/04/03
ジャーナル フリーUnconventional oil and gas attract attention as next generation energy, because of their vast amount of resources. A part of the unconventional oil and gas has been already produced on a commercial scale, while the development of some of them is still in the stage of research. This paper first reviews the methodologies for producing unconventional oil and gas, which are already utilized on a commercial basis or are considered to be promising in the research stage. It is, then, introduced how the existing production methods are being improved/modified to increase the productivity of unconventional oil and gas.
In the development of heavy oil/extra heavy oil/bitumen, advanced production methods including the combination of steam and solvent injection as well as the in-situ upgrading are investigated besides conventional steam injection and in-situ combustion. In the shale gas/oil exploitation, it is well-known that the improvement and integration of horizontal well, multi-stage hydraulic fracturing and micro-seismic technologies have made it possible to dramatically increase the production rate. However, the area of high productivity, which is called a ‘sweet spot,’ is confined to small parts of a formation. Toward the identification of this sweet spot, there is a variety of research work conducted, including the examination of the effects of reservoir properties such as natural fracture permeability, matrix permeability and hydraulic fracture length on gas/oil production, and the investigation of the fluid flow mechanism through micro organic pores. The research work for the development of methane hydrate has started recently. Although the superiority of the depressurization method over other methods such as thermal methods has been revealed, the recovery of methane by depressurization is expected to be not more than 50-60%. The methodologies that can be applied in conjunction with and/or after depressurization are being pursued.抄録全体を表示PDF形式でダウンロード (1836K) -
渡邉 則昭, 石橋 琢也, 土屋 範芳, 玉川 哲也2013 年 78 巻 6 号 p. 482-490
発行日: 2013年
公開日: 2015/04/03
ジャーナル フリーWe explore the three-orders-of-magnitude difference in productivity between two wells, observed at the Yufutsu oil/gas field in Hokkaido, Japan. A highly reliable discrete fracture network (DFN) model for this field was previously constructed by integrating 3-D seismic data, well logging data, in-situ stress data, and acoustic emission data during a massive hydraulic injection. However, the huge difference in well productivity was not reproduced even with the highly reliable DFN model. In the present study, different from previous studies, scale-dependent fracture aperture distributions are numerically determined by using pairs of fractal fracture surfaces, and given to the critically stressed fractures in the DFN model. For this DFN model with the aperture distributions, fluid flow simulations are conducted by using a novel simulator, GeoFlow, which has been recently developed by the authors to predict the 3-D channeling flow (formation of preferential flow paths) in a rock fracture network. In the GeoFlow simulations, the huge difference in well productivity, which is never reproduced by conventional DFN simulations with the parallel plate model for fracture flow, is successfully reproduced. It is indicated that, in reality, fluid flow within a fractured reservoir is much more localized than a prediction by the conventional DFN simulation, due to the formation of preferential flow paths, which is likely to impact well productivity. It is therefore desirable to evaluate a distribution of preferential flow paths in a fractured reservoir with the concept of GeoFlow.抄録全体を表示PDF形式でダウンロード (3501K) -
上辻 良平, 熊野 裕介, 横井 悟2013 年 78 巻 6 号 p. 491-495
発行日: 2013年
公開日: 2015/04/03
ジャーナル フリーAyukawa oil and gas field is located in Akita prefecture, Northern part of Japan. In the field, we have frequent and intensive oil show through the Onnagawa shale, which is Miocene, bio-siliceous and known as the main source rock in Japan. Onnagawa is considered to be similar to Monterey shale. Acidizing in Monterey shale has a long history of success. Though the production is generally improved by removing the drilling and completion damage, unexpected favorable responses from low permeability rock are also reported. These improvements are considered to result from dissolving the calcite and clay minerals in natural fractures and enhancing the wellbore connection into natural fracture network. The acid stimulation test was conducted to verify this acidizing effect in Onnagawa shale. The target well showed very low productivity. Weakly fracture distribution is detected from wellbore images. No skin damage and low permeability on the order of 0.01 md were estimated from the pressure analysis. So the objective of this stimulation is not the removal of drilling and completion damage, but the improvement of natural fracture conductivity. The stimulation program was comprised of three stages that alternated 15% HCl preflush, 12% HCl + 3% HF main acid, NH4Cl overflush, and particulate diverting agent. The significant pressure drops indicating the injectivity improvement were observed during both preflush and main acid injection. The oil production dramatically increased from 1.5 kl/day to 50 kl/day. The productivity index also increase from 0.3 kl/day/MPa to 45 kl/day/MPa. This test is the first successful stimulation of the tight oil formation in Japan.抄録全体を表示PDF形式でダウンロード (1038K) -
上谷 高明2013 年 78 巻 6 号 p. 496-499
発行日: 2013年
公開日: 2015/04/03
ジャーナル フリーThe Minami Kuwayama field, one of the largest oil fields in Japan, began production in 2003. Severe asphaltene problems have been experienced in all wells, in both the reservoir and production tubing, and at the surface facilities. We have been operating this field for over 10 years and learned that we could sustain the productivity through the use of chemicals and the control of production rates. This article provides our experience and major findings.抄録全体を表示PDF形式でダウンロード (1020K) -
加藤 広大, 遠藤 健司, 中川 裕幸, 中村 常太2013 年 78 巻 6 号 p. 500-505
発行日: 2013年
公開日: 2015/04/03
ジャーナル フリーHANGINGSTONE oil sands field is approximately 50 km away from Fort McMurray, Alberta province. Japan Petroleum Exploration has been producing bitumen (oil) from this field by SAGD method through overseas subsidiary, Japan Canada Oil sands for over a decade. SAGD stands for Steam Assisted Gravity Drainage and steam is injected into oil sands reservoir to decrease the viscosity of bitumen in this process, while mobile oil is produced by the gravity force simultaneously. The production performance of SAGD is significantly affected according to geological heterogeneities and reservoir parameters such as permeability. Therefore, highly detailed geological models have been constructed to evaluate the production performance, operation strategies and new technologies applied to future green fields. Simulation approaches are considered of value in terms of its flexibility. Although base work flow of our simulation approach has been established in this work, a couple of parts of the work flow need to be brushed up further to make it applicable to future evaluations.抄録全体を表示PDF形式でダウンロード (1318K)
論説
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アッターウィカムトン ウィサルット, ビルカエス ハビエル, 佐藤 光三2013 年 78 巻 6 号 p. 508-519
発行日: 2013年
公開日: 2015/04/03
ジャーナル フリーメタモデリングは, 数値シミュレーション応答と入力パラメータの間の数学的連関を構築するために使用される強力なツールであり, この連関は, 時間とコストのかかる貯留層シミュレーションの代わりに利用することができる。本研究は, パタニ盆地におけるガス攻法石油増進回収 (EOR) の評価のためにメタモデリングを使用することの実現可能性を探るものである。パタニ盆地の数千に上る貯留層に対する個別のシミュレーションは現実的でないことがその理由である。メタモデルとしては, パラメトリックメタモデルとノンパラメトリックメタモデルの2種類を構築した。パラメトリックメタモデルは実験計画法や回帰分析に, またノンパラメトリックメタモデルは交互条件付き期待値法に基づいている。これらのメタモデルならびに, シミュレーションに必要な流体および貯留層物性特性データを得る手法論の両方を検証するために, 実際のフィールドデータを用いたモンテカルロ・シミュレーションを行った。構築されたメタモデルを使用して得られた結果によれば, 圧入ガスとしてメタンを用いる場合, 水・ガスのダブルサイクル注入 (Double Cycle WAG) が最良のガス攻法EORであると結論される。この方法では, 水攻法に比べて原始埋蔵量 (OOIP) の4.4%分を多く増進回収することができる。一方メタンの代わりに二酸化炭素を用いる場合には, 水・ガスの同時注入 (Simultaneous WAG) が最良のガス攻法EORである。この方法では, 水攻法よりもOOIPの7.8%分を多く回収できる。これらの結果は, 流体および貯留層物性特性の詳細なデータに欠けるパタニ盆地の多数の貯留層において, メタモデリングによる対処の実現可能性を示すものである。抄録全体を表示PDF形式でダウンロード (1371K)
解説
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大東 昌記, 稲田 徳弘2013 年 78 巻 6 号 p. 520-523
発行日: 2013年
公開日: 2015/04/03
ジャーナル フリーIn 1997, JNOC (the present JOGMEC) introduced the drilling simulator DS-5000 Classic in Kashiwazaki Test Field. This simulator is used for training school on well control, and this training can lead to the issuance of an IADC WellCAP certificate. The simulator can reproduce an environment similar to that in actual drilling operations and is useful for accident prevention as well as personnel training. However, because the DS-5000 has been in operation for ten years or more, various problems (such as loose connections) have been occurring. Therefore, we decided to overhaul and revamp the equipment and upgrade the software of the DS-5000. In addition, we introduced a new simulator, the DS-600. The DS-600 imitates an automated control system, which is being applied in the latest drilling rigs. From now on, we are planning to use these two simulators for new training courses besides those on well control.抄録全体を表示PDF形式でダウンロード (1218K)
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