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/3114/\r\n\r \nEvent Title: Westside: Fracture Complexity: Signature Pressure Behavior and Analysis Methodology \r\nStart Date / Time: Jan 20, 2016 11:30 AM Amer ica/Chicago\r\nLocation: Norris Westchase Center\r\nSpeaker: Lucas Bazan, Consultant, Bazan Consulting \r\nGoogle\r\nhttp://maps.google.com/maps?q=9 990+Richmond+Ave.,+Suite+102,Houston,TX,77042\r\n\r\nForecast\nhttp://www. weather.com/weather/monthly/77042\r\n\r\nDuring hydraulic fracture propaga tion three regions may be identified from the pressure response, referred to as: 1) near-well, that extends tens of inches, 2) mid-field, that exten ds tens of feet and 3) far-field, which extends hundreds of feet from the wellbore. Each region can experience simple, tortuous, and complex fractu re behavior, creating unique pressure signatures. In unconventional reser voirs geomechanical conditions may allow the creation of complex fracture networks (i.e., non-planar propagation) that can be initiated and propagat ed in multiple planes and generally having a dominant or primary fracture. \r\nSpecific to highly deviated and horizontal wellbores, complexity mani fests itself as turning, twisting and longitudinal events as hydraulic fra ctures propagate in the near and mid-field regions, and then reorient in t he direction of principal stress planes in the far-field. This creates an increased fracturing pressure that does not diminish instantly when the f racture treatment is shut-in and results in anomalously high apparent net pressures, as evidenced by amplified ISIP&rsquo\;s and rapidly declining p ressures that dissipate minutes after shut-in. High apparent fracturing s tress gradients are often seen that are much greater than the overburden s tress gradients. Although suggestive, these high stress gradients are not indicative of horizontal fractures in the far-field, but rather related t o fracture complexity in the mid-field. Understanding mid-field fracture complexity is critical in interpreting fracture treatment pressure respons es and optimizing treatment designs in multi-stage/multi-cluster horizonta l wells. This presentation discusses methods to properly identify and inc orporate complex fracture pressure interpretation for fracture treatment d esign, post-job pressure matching and stage/cluster spacing designs relate d to fracture interference.--- This iCal file does *NOT* confirm registrat ion.Event details subject to change. ---\r\n\r\n--- By Tendenci - The Open Source AMS for Associations ---\r\n UID:uid3114@spegcs.org SUMMARY:Westside: Fracture Complexity: Signature Pressure Behavior and Analysis Methodology DTSTART:20160120T173000Z DTEND:20160120T190000Z CLASS:PUBLIC PRIORITY:5 DTSTAMP:20240329T052455Z TRANSP:OPAQUE SEQUENCE:0 LOCATION:Norris Westchase Center X-ALT-DESC;FMTTYPE=text/html:
During hydraulic fracture propagation three regions may be identifie d from the pressure response, referred to as: 1) near-well, that extends t ens of inches, 2) mid-field, that extends tens of feet and 3) far-field, w hich extends hundreds of feet from the wellbore. \; Each region can ex perience simple, tortuous, and complex fracture behavior, creating unique pressure signatures. \; In unconventional reservoirs geomechanical con ditions may allow the creation of complex fracture networks (i.e., non-pla nar propagation) that can be initiated and propagated in multiple planes a nd generally having a dominant or primary fracture. \;
Specific to highly deviated and horizontal wellbores, complexity manifests itself as turning, twisting and longitudinal events as hydraulic fractures propag ate in the near and mid-field regions, and then reorient in the direction of principal stress planes in the far-field. \; This creates an increa sed fracturing pressure that does not diminish instantly when the fracture treatment is shut-in and results in anomalously high apparent net pressur es, as evidenced by amplified ISIP&rsquo\;s and rapidly declining pressure s 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 ar e not indicative of horizontal fractures in the far-field, but rather rela ted to fracture complexity in the mid-field. \; Understanding mid-fiel d fracture complexity is critical in interpreting fracture treatment press ure responses and optimizing treatment designs in multi-stage/multi-cluste r horizontal wells. \; This presentation discusses methods to properly identify and incorporate complex fracture pressure interpretation for fra cture treatment design, post-job pressure matching and stage/cluster spaci ng designs related to fracture interference.