BEGIN:VCALENDAR VERSION:2.0 METHOD:PUBLISH PRODID:-//Tendenci - The Open Source AMS for Associations//Tendenci Codeba se MIMEDIR//EN BEGIN:VEVENT DESCRIPTION:--- This iCal file does *NOT* confirm registration.\r\nEvent d etails subject to change. ---\r\nhttps://www.spegcs.org/events/3146/\r\n\r \nEvent Title: Westside WEBINAR ONLY: Fracture Complexity: Signature Press ure Behavior and Analysis Methodology \r\nStart Date / Time: Jan 20, 2016 12:00 PM America/Chicago\r\nLocation: At your desk\r\nSpeaker: Lucas Bazan , Consultant, Bazan Consulting \r\n \r\nDuring hydraulic fracture propagat ion three regions may be identified from the pressure response, referred t o as: 1) near-well, that extends tens of inches, 2) mid-field, that extend s tens of feet and 3) far-field, which extends hundreds of feet from the w ellbore. Each region can experience simple, tortuous, and complex fractur e behavior, creating unique pressure signatures. In unconventional reserv oirs geomechanical conditions may allow the creation of complex fracture n etworks (i.e., non-planar propagation) that can be initiated and propagate d in multiple planes and generally having a dominant or primary fracture. \r\nSpecific to highly deviated and horizontal wellbores, complexity manif ests itself as turning, twisting and longitudinal events as hydraulic frac tures propagate in the near and mid-field regions, and then reorient in th e direction of principal stress planes in the far-field. This creates an increased fracturing pressure that does not diminish instantly when the fr acture treatment is shut-in and results in anomalously high apparent net p ressures, as evidenced by amplified ISIP&rsquo\;s and rapidly declining pr essures that dissipate minutes after shut-in. High apparent fracturing st ress gradients are often seen that are much greater than the overburden st ress gradients. Although suggestive, these high stress gradients are not indicative of horizontal fractures in the far-field, but rather related to fracture complexity in the mid-field. Understanding mid-field fracture c omplexity is critical in interpreting fracture treatment pressure response s and optimizing treatment designs in multi-stage/multi-cluster horizontal wells. This presentation discusses methods to properly identify and inco rporate complex fracture pressure interpretation for fracture treatment de sign, post-job pressure matching and stage/cluster spacing designs related to fracture interference.--- This iCal file does *NOT* confirm registrati on.Event details subject to change. ---\r\n\r\n--- By Tendenci - The Open Source AMS for Associations ---\r\n UID:uid3146@spegcs.org SUMMARY:Westside WEBINAR ONLY: Fracture Complexity: Signature Pressure Behavior and Analysis Methodology DTSTART:20160120T180000Z DTEND:20160120T190000Z CLASS:PUBLIC PRIORITY:5 DTSTAMP:20240328T222112Z TRANSP:OPAQUE SEQUENCE:0 LOCATION:At your desk X-ALT-DESC;FMTTYPE=text/html:
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D uring hydraulic fracture propagation three regions may be identified from the pressure response, referred to as: 1) near-well, that extends tens of inches, 2) mid-field, that extends tens of feet and 3) far-field, which ex tends hundreds of feet from the wellbore. \; Each region can experienc e simple, tortuous, and complex fracture behavior, creating unique pressur e signatures. \; In unconventional reservoirs geomechanical conditions may allow the creation of complex fracture networks (i.e., non-planar pro pagation) that can be initiated and propagated in multiple planes and gene rally having a dominant or primary fracture. \;
Specific to hig hly deviated and horizontal wellbores, complexity manifests itself as turn ing, twisting and longitudinal events as hydraulic fractures propagate in the near and mid-field regions, and then reorient in the direction of prin cipal stress planes in the far-field. \; This creates an increased fra cturing pressure that does not diminish instantly when the fracture treatm ent is shut-in and results in anomalously high apparent net pressures, as evidenced by amplified ISIP&rsquo\;s and rapidly declining pressures that dissipate minutes after shut-in. \; High apparent fracturing stress gr adients are often seen that are much greater than the overburden stress gr adients. \; Although suggestive, these high stress gradients are not i ndicative of horizontal fractures in the far-field, but rather related to fracture complexity in the mid-field. \; Understanding mid-field fract ure complexity is critical in interpreting fracture treatment pressure res ponses and optimizing treatment designs in multi-stage/multi-cluster horiz ontal wells. \; This presentation discusses methods to properly identi fy and incorporate complex fracture pressure interpretation for fracture t reatment design, post-job pressure matching and stage/cluster spacing desi gns related to fracture interference.