多学科数据收集,以表征水力压裂性能和评估Bakken井距

A. Lorwongngam, C. Cipolla, C. Gradl, Jose Gil Cidoncha, Bruce Davis
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引用次数: 6

摘要

为了有效地从非常规油气藏中抽取油气,运营商多年来一直在优化钻井间距单元(DSU)井距。本文介绍了Bakken井距的持续改进,利用更小间距的试验垫块和多学科数据收集来了解最有效的井间距。在East Nesson (EN)地区[Alger油田],作业公司对Middle Bakken (MB)井的标准井距为500 ~ 700英尺。为了了解该地区的最佳井距,作业公司对类似地层之间的井距进行了500英尺的试验。Middle Bakken井和Three Forks井之间的井距为250英尺。在井距试验期间收集的数据包括微地震、微地震枯竭圈闭(MDD)、放射性(RA)示踪剂、化学示踪剂、图像测井、完井/返排/早期生产期间的压力测量以及裂缝注入诊断测试(DFITs)。这些数据用于校准先进的水力裂缝模型,并指导下一代油藏模拟历史匹配,以表征多井生产行为。母井的MDD提供了“绘制”排水模式的数据,表明排水仅限于MB地层。然而,微地震数据显示,水力裂缝高度从Three Forks第二区块(TF2)向上延伸,穿过Three Forks第一区块(TF1)、Middle Bakken,并进入上覆的Lodgepole (LP),连接了整个Bakken油气系统。微地震还显示了DSU中裂缝向母井方向的不对称生长,但随着完井远离母井,这种不对称逐渐减弱。除了微地震显示的MB-TF连通性外,还在Middle Bakken井中检测到从TF2井泵送的RA示踪剂。隐含的支撑剂从较低的TF完井到MB的传输增加了地层之间生产通信的可能性。无论地层如何,在水力压裂作业中,从区块的一端到另一端(超过2500英尺)都可以发现化学示踪剂(油和水);再次确认了Middle Bakken井和Three Forks井之间的水力通信。水力裂缝模型使用微地震数据进行校准,并用于后续的油藏模拟历史匹配。该工作流程包括母井水力裂缝建模和历史生产匹配,进行地质力学建模以确定母井枯竭对三维应力状态的影响,用于填充井水力裂缝建模,以及整个区块的生产历史匹配。模拟结果显示,裂缝与裂缝之间存在明显的连通和井与井之间的干扰。作业者迅速利用这些知识来优化整个区域的井距,以最大化DSU值。
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Multidisciplinary Data Gathering to Characterize Hydraulic Fracture Performance and Evaluate Well Spacing in the Bakken
To effectively drain hydrocarbon from unconventional plays, operators have been optimizing their drilling spacing unit (DSU) well spacing for many years. This paper presents a continuous improvement of Bakken well spacing using trial pads with smaller spacing and multidisciplinary data gathering to understand the most effective spacing between wells. The operator's standard well spacing between Middle Bakken (MB) wells in the East Nesson (EN) area [Alger Field] ranges from 500 to 700 ft. To understand the optimum spacing between wells in this area, the operator trialed well spacing of 500 ft between like formations. The spacing between Middle Bakken and Three Forks wells was 250 ft. Data gathered during the spacing trial included microseismic, microseismic depletion delineation (MDD), radioactive (RA) tracers, chemical tracers, image logs, pressure measurements during completion/flowback/early-time production, and diagnostic fracture injection tests (DFITs). The data was used to calibrate advanced hydraulic fracture models and guide next-generation reservoir simulation history matching to characterize multiwell production behavior. The MDD in the parent well provided data to "map" drainage patterns, showing that drainage was limited to the MB formation. However, microseismic showed that hydraulic fracture height extended from the Three Forks second bench (TF2) up through the Three Forks first bench (TF1), Middle Bakken, and into the overlying Lodgepole (LP)—connecting the entire Bakken petroleum system. The microseismic also showed asymmetric fracture growth toward the parent well in the DSU, but the asymmetry diminished as completions progressed away from the parent well. In addition to the MB-TF connectivity indicated from the microseismic, RA tracers pumped from a TF2 well were detected in a Middle Bakken well. The implied transport of proppant from a lower TF completion to the MB increases the likelihood of production communication between formations. Chemical tracers (oil and water) pumped during hydraulic fracturing operations were found from one end of the pad to another (over 2,500 ft) regardless of formation; another confirmation of hydraulic communication between Middle Bakken and Three Forks wells. The hydraulic fracture model was calibrated using microseismic data and used for subsequent reservoir simulation history matching. The workflow consisted of modeling the parent well hydraulic fractures and history matching production, performing geomechanical modeling to determine the effects of parent well depletion on 3D stress state for hydraulic fracture modeling of the infill wells, and production history matching of the entire pad. The modeling showed significant fracture-to-fracture communication and well-to-well interference. The operator quickly used these learnings to optimize well spacing across the area to maximize DSU value.
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