{"id":16046,"date":"2026-03-01T00:16:32","date_gmt":"2026-03-01T00:16:32","guid":{"rendered":"https:\/\/www.hnjournal.net\/?page_id=16046"},"modified":"2026-03-01T00:16:34","modified_gmt":"2026-03-01T00:16:34","slug":"7-3-13","status":"publish","type":"page","link":"https:\/\/www.hnjournal.net\/ar\/7-3-13\/","title":{"rendered":""},"content":{"rendered":"<div class=\"journal-article\" style=\"margin-bottom: 20px;\"><h3 style='text-align: left; font-family:Times New Roman;'>Applying the TDS Technique to Identify and Analysis Wellbore Storage Effects<\/h3><h4 style='text-align: right; font-family:Simplified Arabic;'>\u062a\u0637\u0628\u064a\u0642 \u062a\u0642\u0646\u064a\u0629 \u0627\u0644\u062a\u062e\u0644\u064a\u0642 \u0627\u0644\u0645\u0628\u0627\u0634\u0631 (TDS) \u0641\u064a \u062a\u062d\u062f\u064a\u062f \u0648\u062a\u062d\u0644\u064a\u0644 \u062a\u0623\u062b\u064a\u0631 \u062e\u0632\u0646 \u0627\u0644\u0628\u0626\u0631<\/h4><p style='text-align: left; font-weight:bold;'>Laila D. Saleh<sup>1<\/sup>*, Abdussalam M. Mohamed<sup>1<\/sup>, Mohammed H. Lagha<sup>1<\/sup>, Moaid A. Alsagatti<sup>1<\/sup>, Ahmed Y. Algizawi<sup>1<\/sup><\/p><div style='direction: ltr; text-align: left; font-size:12px; line-height:1.5;'><p><sup>1<\/sup>Department of Petroleum Engineering, University of Tripoli, Tripoli, Libya.<\/p><p>*Corresponding Author: ladasa08@gmail.com    l.saleh@uot.edu.ly<\/p><\/div><p style='text-align:left;'><strong>DOI:<\/strong> <a href='https:\/\/doi.org\/https:\/\/doi.org\/10.53796\/hnsj73\/13' target='_blank' rel='noopener'>https:\/\/doi.org\/10.53796\/hnsj73\/13<\/a><\/p><p style='text-align: left;'><strong>Arabic Scientific Research Identifier:<\/strong> <a href='https:\/\/arsri.org\/10000\/73\/13' target='_blank' rel='noopener'>https:\/\/arsri.org\/10000\/73\/13<\/a><\/p><p style='text-align: left;'><strong>Volume (7) Issue (3). Pages:<\/strong> 196 - 209<\/p><p style='text-align: left;'><strong>Received at:<\/strong> 2026-02-12 | <strong>Accepted at:<\/strong> 2026-02-19 | <strong>Published at:<\/strong> 2026-03-01<\/p><p><a href='\/volume7\/issue3\/7-3-13.pdf' target='_blank' rel='noopener' style='background-color:green;color:white;padding:10px 15px;text-decoration:none;border-radius:5px;'>Download PDF<\/a><\/p>\r\n<style>\r\n.hnsj-cite-btn{\r\n  display:inline-flex; gap:8px; align-items:center;\r\n  padding:10px 14px; border-radius:10px;\r\n  border:1px solid #0b5ed7; background:#0b5ed7; color:#fff;\r\n  cursor:pointer; font-weight:700;\r\n}\r\n.hnsj-cite-btn:hover{background:#084bb0;border-color:#084bb0}\r\n.hnsj-cite-note{display:block;margin-top:6px;font-size:13px;opacity:.85}\r\n\r\n.hnsj-modal-backdrop{\r\n  position:fixed; inset:0; background:rgba(0,0,0,.55);\r\n  display:none; z-index:99998;\r\n}\r\n.hnsj-modal{\r\n  position:fixed; left:50%; top:50%; transform:translate(-50%,-50%);\r\n  width:min(760px,94vw); background:#fff; border-radius:14px;\r\n  box-shadow:0 12px 35px rgba(0,0,0,.28);\r\n  display:none; z-index:99999; overflow:hidden;\r\n  border:1px solid rgba(0,0,0,.08);\r\n}\r\n\r\n.hnsj-modal-header{\r\n  display:flex; justify-content:space-between; align-items:center;\r\n  padding:14px 16px; border-bottom:1px solid #eee; background:#f8fafc;\r\n}\r\n.hnsj-modal-title{font-size:16px;font-weight:800;color:#111827}\r\n.hnsj-modal-close{\r\n  border:1px solid #d1d5db; background:#fff;\r\n  width:34px; height:34px; border-radius:10px;\r\n  font-size:18px; cursor:pointer; line-height:0; color:#111827;\r\n}\r\n.hnsj-modal-close:hover{background:#f3f4f6}\r\n\r\n.hnsj-tabs{\r\n  display:flex; gap:10px; padding:10px 16px;\r\n  border-bottom:1px solid #f0f0f0; justify-content:flex-end;\r\n}\r\n.hnsj-tab{\r\n  padding:10px 14px; border-radius:10px;\r\n  border:1px solid #cfcfcf; background:#f3f4f6;\r\n  cursor:pointer; font-weight:800; color:#111827;\r\n}\r\n.hnsj-tab:hover{background:#e5e7eb;border-color:#9ca3af}\r\n.hnsj-tab.active{\r\n  background:#0b5ed7; border-color:#0b5ed7; color:#fff;\r\n  box-shadow:0 2px 10px rgba(11,94,215,.18);\r\n}\r\n\r\n.hnsj-modal-body{padding:14px 16px}\r\n.hnsj-row{\r\n  display:flex; gap:10px; flex-wrap:wrap; align-items:center;\r\n  margin-bottom:10px; justify-content:flex-end;\r\n}\r\n.hnsj-select{\r\n  padding:10px 12px; border-radius:10px;\r\n  border:1px solid #cfcfcf; min-width:220px;\r\n  background:#fff; color:#111827; font-weight:700;\r\n}\r\n.hnsj-copy{\r\n  padding:10px 14px; border-radius:10px;\r\n  border:1px solid #0b5ed7; background:#0b5ed7; color:#fff;\r\n  cursor:pointer; font-weight:800;\r\n}\r\n.hnsj-copy:hover{background:#084bb0;border-color:#084bb0}\r\n\r\n.hnsj-textarea{\r\n  width:100%; min-height:130px; padding:12px;\r\n  border-radius:12px; border:1px solid #cfcfcf;\r\n  line-height:1.7; resize:vertical; color:#111827; background:#fff;\r\n}\r\n.hnsj-actions{display:flex; justify-content:space-between; align-items:center; margin-top:10px; gap:10px; flex-wrap:wrap;}\r\n.hnsj-dl{\r\n  padding:10px 14px;\r\n  border-radius:10px;\r\n  border:1px solid #0b5ed7;\r\n  background:#0b5ed7;\r\n  color:#fff;\r\n  cursor:pointer;\r\n  font-weight:800;\r\n}\r\n.hnsj-dl:hover{background:#084bb0;border-color:#084bb0}\r\n\/* Force the citation modal UI to be independent from site RTL\/LTR *\/\r\n.hnsj-modal,\r\n.hnsj-modal *{\r\n  direction: ltr;\r\n  text-align: left;\r\n}\r\n\r\n\/* Keep the header title readable *\/\r\n.hnsj-modal-header{\r\n  direction: ltr;\r\n}\r\n<\/style>\r\n\r\n<script>\r\n(function(){\r\n  function slugifyFileName(s){\r\n    return (s || 'citation')\r\n      .toString()\r\n      .trim()\r\n      .replace(\/^https?:\\\/\\\/\/i,'')\r\n      .replace(\/[^a-z0-9]+\/gi,'-')\r\n      .replace(\/-+\/g,'-')\r\n      .replace(\/^-|-$\/g,'')\r\n      .toLowerCase();\r\n  }\r\n\r\n  function downloadTextFile(filename, content, mime){\r\n    var blob = new Blob([content], { type: mime || 'text\/plain;charset=utf-8' });\r\n    var url = URL.createObjectURL(blob);\r\n    var a = document.createElement('a');\r\n    a.href = url;\r\n    a.download = filename;\r\n    document.body.appendChild(a);\r\n    a.click();\r\n    a.remove();\r\n    setTimeout(function(){ URL.revokeObjectURL(url); }, 500);\r\n  }\r\n\r\n  function splitAuthors(str){\r\n    if(!str) return [];\r\n    return str\r\n      .split(\/,|\u061b|\u060c|;|\\n\/g)\r\n      .map(s => s.trim())\r\n      .filter(Boolean);\r\n  }\r\n\r\n  function buildRIS(m, langKey){\r\n    const title   = (langKey === 'ar') ? 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Saleh*, Abdussalam M. Mohamed, Mohammed H. Lagha, Moaid A. Alsagatti, Ahmed Y. Algizawi&quot;,&quot;authors_ar&quot;:&quot;Laila D. Saleh*, Abdussalam M. Mohamed, Mohammed H. Lagha, Moaid A. Alsagatti, Ahmed Y. Algizawi&quot;,&quot;title_en&quot;:&quot;Applying the TDS Technique to Identify and Analysis Wellbore Storage Effects&quot;,&quot;title_ar&quot;:&quot;\u062a\u0637\u0628\u064a\u0642 \u062a\u0642\u0646\u064a\u0629 \u0627\u0644\u062a\u062e\u0644\u064a\u0642 \u0627\u0644\u0645\u0628\u0627\u0634\u0631 (TDS) \u0641\u064a \u062a\u062d\u062f\u064a\u062f \u0648\u062a\u062d\u0644\u064a\u0644 \u062a\u0623\u062b\u064a\u0631 \u062e\u0632\u0646 \u0627\u0644\u0628\u0626\u0631&quot;,&quot;journal_en&quot;:&quot;Humanities &amp; Natural Sciences Journal&quot;,&quot;journal_ar&quot;:&quot;\u0645\u062c\u0644\u0629 \u0627\u0644\u0639\u0644\u0648\u0645 \u0627\u0644\u0627\u0646\u0633\u0627\u0646\u064a\u0629 \u0648\u0627\u0644\u0637\u0628\u064a\u0639\u064a\u0629&quot;,&quot;year&quot;:&quot;2026&quot;,&quot;volume&quot;:&quot;7&quot;,&quot;issue&quot;:&quot;3&quot;,&quot;doi&quot;:&quot;https:\\\/\\\/doi.org\\\/10.53796\\\/hnsj73\\\/13&quot;,&quot;url&quot;:&quot;https:\\\/\\\/www.hnjournal.net\\\/7-3-13\\\/&quot;,&quot;published_at&quot;:&quot;2026-03-01&quot;}' data-cit-en='{&quot;APA&quot;:&quot;Saleh L. D., Mohamed A. M., Lagha M. H., Alsagatti M. A., Algizawi A. Y.. (2026). Applying the TDS Technique to Identify and Analysis Wellbore Storage Effects. Humanities &amp; Natural Sciences Journal, 7(3). https:\\\/\\\/doi.org\\\/10.53796\\\/hnsj73\\\/13&quot;,&quot;Chicago&quot;:&quot;Saleh Laila D., Mohamed Abdussalam M., Lagha Mohammed H., Alsagatti Moaid A., Algizawi Ahmed Y.. 2026. \\&quot;Applying the TDS Technique to Identify and Analysis Wellbore Storage Effects.\\&quot; Humanities &amp; Natural Sciences Journal 7, no. 3. https:\\\/\\\/doi.org\\\/10.53796\\\/hnsj73\\\/13&quot;,&quot;Harvard&quot;:&quot;Saleh L. D., Mohamed A. M., Lagha M. H., Alsagatti M. A., Algizawi A. Y.. 2026. Applying the TDS Technique to Identify and Analysis Wellbore Storage Effects. Humanities &amp; Natural Sciences Journal. [Internet] 2026-03-01. [Cited 2026-04-24]. 7(3). Available at: https:\\\/\\\/www.hnjournal.net\\\/7-3-13\\\/. https:\\\/\\\/doi.org\\\/10.53796\\\/hnsj73\\\/13&quot;,&quot;Vancouver&quot;:&quot;Saleh L. D., Mohamed A. M., Lagha M. H., Alsagatti M. A., Algizawi A. Y.. Applying the TDS Technique to Identify and Analysis Wellbore Storage Effects. Humanities &amp; Natural Sciences Journal. [Internet]. 2026-03-01; 7(3). Available from: https:\\\/\\\/doi.org\\\/10.53796\\\/hnsj73\\\/13&quot;,&quot;IEEE&quot;:&quot;Saleh L. D., Mohamed A. M., Lagha M. H., Alsagatti M. A., Algizawi A. Y., \\&quot;Applying the TDS Technique to Identify and Analysis Wellbore Storage Effects,\\&quot; Humanities &amp; Natural Sciences Journal, vol. 7, no. 3, 2026. https:\\\/\\\/doi.org\\\/10.53796\\\/hnsj73\\\/13&quot;,&quot;MLA&quot;:&quot;Saleh Laila D., Mohamed Abdussalam M., Lagha Mohammed H., Alsagatti Moaid A., Algizawi Ahmed Y.. \\&quot;Applying the TDS Technique to Identify and Analysis Wellbore Storage Effects.\\&quot; Humanities &amp; Natural Sciences Journal, vol. 7, no. 3, 2026-03-01, https:\\\/\\\/doi.org\\\/10.53796\\\/hnsj73\\\/13&quot;}' data-cit-ar='{&quot;APA&quot;:&quot;Saleh L. D, Mohamed A. M, Lagha M. H, Alsagatti M. A., Algizawi A. Y. (2026). \u062a\u0637\u0628\u064a\u0642 \u062a\u0642\u0646\u064a\u0629 \u0627\u0644\u062a\u062e\u0644\u064a\u0642 \u0627\u0644\u0645\u0628\u0627\u0634\u0631 (TDS) \u0641\u064a \u062a\u062d\u062f\u064a\u062f \u0648\u062a\u062d\u0644\u064a\u0644 \u062a\u0623\u062b\u064a\u0631 \u062e\u0632\u0646 \u0627\u0644\u0628\u0626\u0631. \u0645\u062c\u0644\u0629 \u0627\u0644\u0639\u0644\u0648\u0645 \u0627\u0644\u0627\u0646\u0633\u0627\u0646\u064a\u0629 \u0648\u0627\u0644\u0637\u0628\u064a\u0639\u064a\u0629\u060c 7(3). https:\\\/\\\/doi.org\\\/10.53796\\\/hnsj73\\\/13&quot;,&quot;Chicago&quot;:&quot;Saleh Laila D, Mohamed Abdussalam M, Lagha Mohammed H, Alsagatti Moaid A., Algizawi Ahmed Y.. 2026. \u00ab\u062a\u0637\u0628\u064a\u0642 \u062a\u0642\u0646\u064a\u0629 \u0627\u0644\u062a\u062e\u0644\u064a\u0642 \u0627\u0644\u0645\u0628\u0627\u0634\u0631 (TDS) \u0641\u064a \u062a\u062d\u062f\u064a\u062f \u0648\u062a\u062d\u0644\u064a\u0644 \u062a\u0623\u062b\u064a\u0631 \u062e\u0632\u0646 \u0627\u0644\u0628\u0626\u0631\u00bb. \u0645\u062c\u0644\u0629 \u0627\u0644\u0639\u0644\u0648\u0645 \u0627\u0644\u0627\u0646\u0633\u0627\u0646\u064a\u0629 \u0648\u0627\u0644\u0637\u0628\u064a\u0639\u064a\u0629\u060c 7(3). https:\\\/\\\/doi.org\\\/10.53796\\\/hnsj73\\\/13&quot;,&quot;Harvard&quot;:&quot;Saleh L. D, Mohamed A. M, Lagha M. H, Alsagatti M. A., Algizawi A. Y. \u062a\u0637\u0628\u064a\u0642 \u062a\u0642\u0646\u064a\u0629 \u0627\u0644\u062a\u062e\u0644\u064a\u0642 \u0627\u0644\u0645\u0628\u0627\u0634\u0631 (TDS) \u0641\u064a \u062a\u062d\u062f\u064a\u062f \u0648\u062a\u062d\u0644\u064a\u0644 \u062a\u0623\u062b\u064a\u0631 \u062e\u0632\u0646 \u0627\u0644\u0628\u0626\u0631. \u0645\u062c\u0644\u0629 \u0627\u0644\u0639\u0644\u0648\u0645 \u0627\u0644\u0627\u0646\u0633\u0627\u0646\u064a\u0629 \u0648\u0627\u0644\u0637\u0628\u064a\u0639\u064a\u0629. [\u0627\u0646\u062a\u0631\u0646\u062a] 2026-03-01. [\u062a\u0627\u0631\u064a\u062e \u0627\u0644\u0648\u0635\u0648\u0644 2026-04-24]. 7(3). \u0645\u062a\u0627\u062d \u0639\u0644\u0649: https:\\\/\\\/www.hnjournal.net\\\/7-3-13\\\/. https:\\\/\\\/doi.org\\\/10.53796\\\/hnsj73\\\/13&quot;,&quot;Vancouver&quot;:&quot;Saleh L. D, Mohamed A. M, Lagha M. H, Alsagatti M. A., Algizawi A. Y. \u062a\u0637\u0628\u064a\u0642 \u062a\u0642\u0646\u064a\u0629 \u0627\u0644\u062a\u062e\u0644\u064a\u0642 \u0627\u0644\u0645\u0628\u0627\u0634\u0631 (TDS) \u0641\u064a \u062a\u062d\u062f\u064a\u062f \u0648\u062a\u062d\u0644\u064a\u0644 \u062a\u0623\u062b\u064a\u0631 \u062e\u0632\u0646 \u0627\u0644\u0628\u0626\u0631. \u0645\u062c\u0644\u0629 \u0627\u0644\u0639\u0644\u0648\u0645 \u0627\u0644\u0627\u0646\u0633\u0627\u0646\u064a\u0629 \u0648\u0627\u0644\u0637\u0628\u064a\u0639\u064a\u0629. [\u0627\u0646\u062a\u0631\u0646\u062a]. 2026-03-01\u061b 7(3). \u0645\u062a\u0627\u062d \u0645\u0646: https:\\\/\\\/doi.org\\\/10.53796\\\/hnsj73\\\/13&quot;,&quot;IEEE&quot;:&quot;Saleh L. D, Mohamed A. M, Lagha M. H, Alsagatti M. A., Algizawi A. Y. \u00ab\u062a\u0637\u0628\u064a\u0642 \u062a\u0642\u0646\u064a\u0629 \u0627\u0644\u062a\u062e\u0644\u064a\u0642 \u0627\u0644\u0645\u0628\u0627\u0634\u0631 (TDS) \u0641\u064a \u062a\u062d\u062f\u064a\u062f \u0648\u062a\u062d\u0644\u064a\u0644 \u062a\u0623\u062b\u064a\u0631 \u062e\u0632\u0646 \u0627\u0644\u0628\u0626\u0631\u00bb. \u0645\u062c\u0644\u0629 \u0627\u0644\u0639\u0644\u0648\u0645 \u0627\u0644\u0627\u0646\u0633\u0627\u0646\u064a\u0629 \u0648\u0627\u0644\u0637\u0628\u064a\u0639\u064a\u0629\u060c \u0645 7\u060c \u0639 3\u060c 2026. https:\\\/\\\/doi.org\\\/10.53796\\\/hnsj73\\\/13&quot;,&quot;MLA&quot;:&quot;Saleh Laila D, Mohamed Abdussalam M, Lagha Mohammed H, Alsagatti Moaid A., Algizawi Ahmed Y.. \u00ab\u062a\u0637\u0628\u064a\u0642 \u062a\u0642\u0646\u064a\u0629 \u0627\u0644\u062a\u062e\u0644\u064a\u0642 \u0627\u0644\u0645\u0628\u0627\u0634\u0631 (TDS) \u0641\u064a \u062a\u062d\u062f\u064a\u062f \u0648\u062a\u062d\u0644\u064a\u0644 \u062a\u0623\u062b\u064a\u0631 \u062e\u0632\u0646 \u0627\u0644\u0628\u0626\u0631\u00bb. \u0645\u062c\u0644\u0629 \u0627\u0644\u0639\u0644\u0648\u0645 \u0627\u0644\u0627\u0646\u0633\u0627\u0646\u064a\u0629 \u0648\u0627\u0644\u0637\u0628\u064a\u0639\u064a\u0629\u060c \u0645 7\u060c \u0639 3\u060c 2026-03-01\u060c https:\\\/\\\/doi.org\\\/10.53796\\\/hnsj73\\\/13&quot;}'>\r\n    <div class='hnsj-modal-header'>\r\n    <div class='hnsj-modal-title'>Cite \/ \u0627\u0644\u0627\u0633\u062a\u0634\u0647\u0627\u062f<\/div>\r\n    <button class='hnsj-modal-close' type='button' data-hnsj-close aria-label='Close'>\u00d7<\/button>\r\n    <\/div>\r\n\r\n    <div class='hnsj-tabs'>\r\n      <button type='button' class='hnsj-tab active' data-lang='en'>English (Roman)<\/button>\r\n      <button type='button' class='hnsj-tab' data-lang='ar'>\u0627\u0644\u0639\u0631\u0628\u064a\u0629<\/button>\r\n    <\/div>\r\n\r\n    <div class='hnsj-modal-body'>\r\n      <div class='hnsj-row'>\r\n        <button type='button' class='hnsj-copy' data-hnsj-copy>Copy<\/button>\r\n        <select class='hnsj-select' data-hnsj-style><\/select>\r\n        <\/div>\r\n\r\n      <textarea class='hnsj-textarea' data-hnsj-box readonly><\/textarea>\r\n\r\n      <div class='hnsj-actions'>\r\n        <div style='display:flex; gap:10px; flex-wrap:wrap;'>\r\n          <button type='button' class='hnsj-dl' data-hnsj-dl='ris'>Download RIS<\/button>\r\n          <button type='button' class='hnsj-dl' data-hnsj-dl='bib'>Download BibTeX<\/button>\r\n        <\/div>\r\n      <\/div>\r\n    <\/div>\r\n  <\/div>\r\n<\/div>\r\n<p style='text-align:justify; direction:ltr;'><strong>Abstract:<\/strong> In many cases some pressure transit analysis tests give missing data for many reasons such as lack of early time pressure points or the test is too short, this makes it difficult to calculate some parameters. The objective of this study is to apply and show the advantage of Tiab\u2019s Direct Synthesis (TDS) technique to estimate the wellbore storage effect when the early time region is missing. TDS technique is a direct method to interpret transient well pressure tests without type curve matching. This method uses log-log plots of the pressure and pressure derivative versus time to compute reservoir parameters such as permeability, wellbore storage, skin factor, half fracture length, drainage area, and distance to the boundaries, etc. This study includes analysis build up test for two oil wells (H1and H2) from X field by using TDS technique advantage which is calculating the wellbore storage effect in case of either unit slope line is not observed or both unit slope line and hump region are not observed.<\/p><p style='text-align:left; direction:ltr;'><strong>Keywords: <\/strong> Pressure, TDS technique, wellbore, unit slope, boundary.<\/p><p style='text-align:justify; direction:rtl;'><strong>\u0627\u0644\u0645\u0633\u062a\u062e\u0644\u0635: <\/strong> \u0641\u064a \u0627\u0644\u0639\u062f\u064a\u062f \u0645\u0646 \u0627\u0644\u062d\u0627\u0644\u0627\u062a\u060c \u062a\u0639\u0637\u064a \u0628\u0639\u0636 \u0627\u062e\u062a\u0628\u0627\u0631\u0627\u062a \u062a\u062d\u0644\u064a\u0644 \u0627\u0644\u0633\u0644\u0648\u0643 \u0627\u0644\u0627\u0646\u062a\u0642\u0627\u0644\u064a \u0644\u0644\u0636\u063a\u0637 \u0628\u064a\u0627\u0646\u0627\u062a \u0646\u0627\u0642\u0635\u0629 \u0644\u0623\u0633\u0628\u0627\u0628 \u0645\u062a\u0639\u062f\u062f\u0629 \u0645\u062b\u0644 \u0639\u062f\u0645 \u062a\u0648\u0641\u0631 \u0646\u0642\u0627\u0637 \u0627\u0644\u0636\u063a\u0637 \u0641\u064a \u0627\u0644\u0632\u0645\u0646 \u0627\u0644\u0645\u0628\u0643\u0631 \u0623\u0648 \u0642\u0650\u0635\u0631 \u0645\u062f\u0629 \u0627\u0644\u0627\u062e\u062a\u0628\u0627\u0631\u060c \u0645\u0645\u0627 \u064a\u062c\u0639\u0644 \u0645\u0646 \u0627\u0644\u0635\u0639\u0628 \u062d\u0633\u0627\u0628 \u0628\u0639\u0636 \u0627\u0644\u0645\u0639\u0627\u0645\u0644\u0627\u062a \u0627\u0644\u0645\u0643\u0645\u0646\u064a\u0629.\r\n\u064a\u0647\u062f\u0641 \u0647\u0630\u0627 \u0627\u0644\u0628\u062d\u062b \u0625\u0644\u0649 \u062a\u0637\u0628\u064a\u0642 \u0648\u0625\u0628\u0631\u0627\u0632 \u0645\u064a\u0632\u0629 \u062a\u0642\u0646\u064a\u0629 \u0627\u0644\u062a\u062e\u0644\u064a\u0642 \u0627\u0644\u0645\u0628\u0627\u0634\u0631 \u0644\u062a\u064a\u0627\u0628 (TDS) \u0641\u064a \u062a\u0642\u062f\u064a\u0631 \u062a\u0623\u062b\u064a\u0631 \u062e\u0632\u0646 \u0627\u0644\u0628\u0626\u0631 \u0639\u0646\u062f \u063a\u064a\u0627\u0628 \u0645\u0646\u0637\u0642\u0629 \u0627\u0644\u0632\u0645\u0646 \u0627\u0644\u0645\u0628\u0643\u0631. \u062a\u064f\u0639\u062f \u062a\u0642\u0646\u064a\u0629 TDS \u0637\u0631\u064a\u0642\u0629 \u0645\u0628\u0627\u0634\u0631\u0629 \u0644\u062a\u0641\u0633\u064a\u0631 \u0627\u062e\u062a\u0628\u0627\u0631\u0627\u062a \u0627\u0644\u0636\u063a\u0637 \u0627\u0644\u0627\u0646\u062a\u0642\u0627\u0644\u064a \u0644\u0644\u0622\u0628\u0627\u0631 \u062f\u0648\u0646 \u0627\u0644\u062d\u0627\u062c\u0629 \u0625\u0644\u0649 \u0645\u0637\u0627\u0628\u0642\u0629 \u0627\u0644\u0645\u0646\u062d\u0646\u064a\u0627\u062a \u0627\u0644\u0642\u064a\u0627\u0633\u064a\u0629 (Type Curve Matching). \u062a\u0639\u062a\u0645\u062f \u0647\u0630\u0647 \u0627\u0644\u062a\u0642\u0646\u064a\u0629 \u0639\u0644\u0649 \u0627\u0644\u0631\u0633\u0648\u0645 \u0627\u0644\u0644\u0648\u063a\u0627\u0631\u064a\u062a\u0645\u064a\u0629 \u0627\u0644\u0645\u0632\u062f\u0648\u062c\u0629 \u0644\u0644\u0636\u063a\u0637 \u0648\u0645\u0634\u062a\u0642 \u0627\u0644\u0636\u063a\u0637 \u0645\u0642\u0627\u0628\u0644 \u0627\u0644\u0632\u0645\u0646 \u0644\u062d\u0633\u0627\u0628 \u0645\u0639\u0627\u0645\u0644\u0627\u062a \u0627\u0644\u0645\u0643\u0645\u0646 \u0645\u062b\u0644 \u0627\u0644\u0646\u0641\u0627\u0630\u064a\u0629\u060c \u0648\u062e\u0632\u0646 \u0627\u0644\u0628\u0626\u0631\u060c \u0648\u0645\u0639\u0627\u0645\u0644 \u0627\u0644\u0633\u0643\u0646 (Skin Factor)\u060c \u0648\u0646\u0635\u0641 \u0637\u0648\u0644 \u0627\u0644\u0643\u0633\u0631\u060c \u0648\u0645\u0633\u0627\u062d\u0629 \u0627\u0644\u062a\u0635\u0631\u064a\u0641\u060c \u0648\u0627\u0644\u0645\u0633\u0627\u0641\u0629 \u0625\u0644\u0649 \u0627\u0644\u062d\u062f\u0648\u062f \u0648\u063a\u064a\u0631\u0647\u0627.\r\n\u064a\u062a\u0636\u0645\u0646 \u0647\u0630\u0627 \u0627\u0644\u0628\u062d\u062b \u062a\u062d\u0644\u064a\u0644 \u0627\u062e\u062a\u0628\u0627\u0631 \u0628\u0646\u0627\u0621 \u0627\u0644\u0636\u063a\u0637 \u0644\u0628\u0626\u0631\u064a\u0646 \u0646\u0641\u0637\u064a\u064a\u0646 (H1 \u0648 H2) \u0645\u0646 \u0627\u0644\u062d\u0642\u0644 X \u0628\u0627\u0633\u062a\u062e\u062f\u0627\u0645 \u0645\u064a\u0632\u0629 \u062a\u0642\u0646\u064a\u0629 TDS\u060c \u0648\u0627\u0644\u062a\u064a \u062a\u062a\u0645\u062b\u0644 \u0641\u064a \u0625\u0645\u0643\u0627\u0646\u064a\u0629 \u062d\u0633\u0627\u0628 \u062a\u0623\u062b\u064a\u0631 \u062e\u0632\u0646 \u0627\u0644\u0628\u0626\u0631 \u0641\u064a \u062d\u0627\u0644 \u0639\u062f\u0645 \u0638\u0647\u0648\u0631 \u062e\u0637 \u0627\u0644\u0645\u064a\u0644 \u0627\u0644\u0623\u062d\u0627\u062f\u064a (Unit Slope Line)\u060c \u0623\u0648 \u0641\u064a \u062d\u0627\u0644 \u0639\u062f\u0645 \u0638\u0647\u0648\u0631 \u0643\u0644\u064d \u0645\u0646 \u062e\u0637 \u0627\u0644\u0645\u064a\u0644 \u0627\u0644\u0623\u062d\u0627\u062f\u064a \u0648\u0645\u0646\u0637\u0642\u0629 \u0627\u0644\u0642\u0645\u0629 (Hump Region).\r\n<\/p><p style='text-align:right;'><strong>\u0627\u0644\u0643\u0644\u0645\u0627\u062a \u0627\u0644\u0645\u0641\u062a\u0627\u062d\u064a\u0629: <\/strong> \u0627\u0644\u0636\u063a\u0637\u060c \u062a\u0642\u0646\u064a\u0629  TDS\u060c \u062e\u0632\u0646 \u0627\u0644\u0628\u0626\u0631\u060c \u0627\u0644\u0645\u064a\u0644 \u0627\u0644\u0623\u062d\u0627\u062f\u064a\u060c \u0627\u0644\u062d\u062f\u0648\u062f \u0627\u0644\u0645\u0643\u0645\u0646\u064a\u0629.<\/p><\/div>\n\n\n<p dir=\"ltr\" style=\"text-align: justify;\"><strong>1. Introduction<\/strong><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Well testing of oil and gas wells is carried out by changing production rate before shutting in the well while recording pressure throughout the entire time of test. The two main objectives of testing an oil or gas well are; first to estimate reservoir parameters, such as permeability, skin factor and average reservoir pressure as well as to analyze reservoir behavior and define reservoir boundary limits [1].<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">A modern interpretation tool known as Tiab&#8217;s Direct Synthesis (TDS) technique which employs the pressure and pressure derivative curves to interpret pressure buildup and drawdown tests without using type-curve matching has been introduced by Tiab (1994 and 1995) [2, 3]. The TDS technique can be easily implemented for all kinds of conventional or unconventional systems. It can be easily applied on cases for which the other methods fail or are difficult to be applied. It is strongly based on the pressure derivative curve. The method works by sector or regions found on the test. This means once a given flow regime is identified, a straight line is drawn throughout it, and then, any arbitrary point on this line and the intersection with other lines as well are used into the appropriate equations for the calculation of reservoir parameters[2].<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">In some real field cases, conventional well test analysis technique face challenge when the radial flow region or wellbore storage regions are not observed on the pressure derivative plot TDS technique addressed this issue by analyzing specific, identifiable points on the derivative curve, which are then substituted into specialized equations .This approach enables the determination of reservoir parameters that would otherwise be unattainable in the absence of a clearly defined flow regimes.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">The application case involving an absent radial flow region was examined in previous study [3]. This study aims to use the TDS technique, for determining the reservoir parameters and wellbore storage effect in case of wellbore storage line is not observed from pressure buildup tests for two oil wells from X field.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2986792\"><\/a><a id=\"post-16046-_Toc3742468\"><\/a><strong>2. Methodology<\/strong><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">TDS technique uses a log-log plot of pressure and pressure derivative data versus time to calculate various reservoirs and well parameters. In this technique, the values of the slopes, intersection points, and beginning and ending times of various straight lines from the log-log plot can be used in exact analytical equations to calculate different parameters as it is shown in the following.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><strong>CASE 1:<\/strong> unit-slope and infinite-acting line are observed; (Fig.1) illustrate this case.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><img loading=\"lazy\" decoding=\"async\" width=\"907\" height=\"400\" class=\"wp-image-16050\" src=\"http:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-1.png\" srcset=\"https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-1.png 907w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-1-300x132.png 300w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-1-768x339.png 768w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-1-18x8.png 18w\" sizes=\"auto, (max-width: 907px) 100vw, 907px\" \/><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2986896\"><\/a><a id=\"post-16046-_Toc3063554\"><\/a> Figure (1): Unit-slope and infinite-acting line are observed<\/p>\n<ul dir=\"ltr\" style=\"text-align: justify;\">\n<li><strong>Wellbore storage effect:<\/strong><\/li>\n<\/ul>\n<p dir=\"ltr\" style=\"text-align: justify;\">Wellbore storage is after flow of fluids into the wellbore after the well is shut-in at the wellhead. During wellbore storage, reservoir effects are masked or distorted, making it impossible to quantify well properties such as permeability, skin and P*. In this case the wellbore storage effect can be calculated from the following equation:<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026. (1)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">The permeability can be determined using infinite acting radial flow line data by using the following equation:<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026. (2)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">The skin factor can be calculated from radial flow pressure and pressure derivative data by using the following equation:<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026. (3)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Pressure loss or gain due to skin calculated by following equation:<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026. (4)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">For a well in the center of a circular reservoir, the average reservoir pressure is obtained from a log\u2010log plot of pressure and pressure derivative versus time according to the following expression:<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u2026. (5)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">the Flow Efficiency can be determined by using the following equation:<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026. (6)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">The Productivity index can be determined by using the following equations:<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026. (7)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026. (8)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><strong>CASE 2:<\/strong> the unit-slope line is not observed (no wellbore storage), (Fig.2) illustrate this case.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><img loading=\"lazy\" decoding=\"async\" width=\"874\" height=\"350\" class=\"wp-image-16051\" src=\"http:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-2.png\" srcset=\"https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-2.png 874w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-2-300x120.png 300w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-2-768x308.png 768w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-2-18x7.png 18w\" sizes=\"auto, (max-width: 874px) 100vw, 874px\" \/><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2986897\"><\/a><a id=\"post-16046-_Toc3063555\"><\/a> Figure (2): The unit-slope line is not observed (no wellbore storage)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">In this case the wellbore storage effect \u201dC \u201c cannot be calculated from equation (1) because absent points in unite slope line ( and ), therefore, the following equation can be used:<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026. (9)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">In case of unit-slope line and Hump (peak) are not observed the effect of wellbore storage can be obtained by estimating time start radial flow () and using following equations:<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026. (10)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026. (11)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">(Fig.3) illustrate the case of unit-slope line and Hump (peak) are not observed.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><img loading=\"lazy\" decoding=\"async\" width=\"869\" height=\"379\" class=\"wp-image-16052\" src=\"http:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-3.png\" srcset=\"https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-3.png 869w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-3-300x131.png 300w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-3-768x335.png 768w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-3-18x8.png 18w\" sizes=\"auto, (max-width: 869px) 100vw, 869px\" \/><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2986898\"><\/a><a id=\"post-16046-_Toc3063556\"><\/a> Figure (3): Unit-slope line and Hump (peak) are not observed<\/p>\n<ul dir=\"ltr\" style=\"text-align: justify;\">\n<li><a id=\"post-16046-_Toc2986795\"><\/a><a id=\"post-16046-_Toc3742471\"><\/a><strong>Boundary effects in diagnostic plots<\/strong><\/li>\n<\/ul>\n<p dir=\"ltr\" style=\"text-align: justify;\">Reservoir boundaries have significant influences on the shape of the diagnostic plot. The effects of boundaries appear following the middle-time region (infinite-acting radial flow) in a test.<\/p>\n<ul dir=\"ltr\" style=\"text-align: justify;\">\n<li><strong>Well in an infinite-acting reservoir:<\/strong><\/li>\n<\/ul>\n<p dir=\"ltr\" style=\"text-align: justify;\">An infinite acting reservoir is a reservoir without any boundaries, therefore boundary effects will not appear on the analysis plots during the duration of the test.<\/p>\n<ul dir=\"ltr\" style=\"text-align: justify;\">\n<li><strong>Constant Pressure Boundary:<\/strong><\/li>\n<\/ul>\n<p dir=\"ltr\" style=\"text-align: justify;\">A constant pressure boundary is a boundary that provides pressure support. This kind of boundary usually occurs in reservoirs with aquifer support. Steady state flow signifies that a constant pressure boundary has been reached.<\/p>\n<ul dir=\"ltr\" style=\"text-align: justify;\">\n<li><strong>No-Flow Boundary:<\/strong><\/li>\n<\/ul>\n<p dir=\"ltr\" style=\"text-align: justify;\">A no-flow boundary is a boundary that does not allow flow through it. This kind of boundary usually occurs in reservoirs with sealing faults or is created between producing wells that are equally spaced and producing at the same rate. Pseudo-steady state flow signifies that all no-flow boundaries have been reached, (Fig.4) illustrates sealing faults cases.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><img loading=\"lazy\" decoding=\"async\" width=\"1366\" height=\"768\" class=\"wp-image-16053\" src=\"http:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-4.png\" srcset=\"https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-4.png 1366w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-4-300x169.png 300w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-4-1024x576.png 1024w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-4-768x432.png 768w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-4-18x10.png 18w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-4-135x75.png 135w\" sizes=\"auto, (max-width: 1366px) 100vw, 1366px\" \/><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2986899\"><\/a><a id=\"post-16046-_Toc3063557\"><\/a> Figure (4): Sealing faults cases <sup>[9]<\/sup>.<\/p>\n<ul dir=\"ltr\" style=\"text-align: justify;\">\n<li><a id=\"post-16046-_Toc2986796\"><\/a><a id=\"post-16046-_Toc3742472\"><\/a><strong>Distance to Boundary<\/strong><\/li>\n<\/ul>\n<p dir=\"ltr\" style=\"text-align: justify;\">The distance to the boundary is the distance between the well and the boundary. The boundary may be a no flow or constant pressure boundary.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">TDS technique can be used to calculate the distance from well to fault by estimating the time at which radial flow regime ends (), and then using the following equation:<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026\u2026. (12)<a id=\"post-16046-_Toc2983394\"><\/a><a id=\"post-16046-_Toc3742473\"><\/a><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><strong>3. Field case<\/strong><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">This study includes using TDS technique on MS Excel software to analysis well test data to calculate wellbore storage effect in two cases (complete test and test without unit slope line), and other properties such as permeability, skin factor, average reservoir pressure, for two wells (H1&amp; H2), which are located in X oilfield in Libya .<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><strong>3.1 Reservoir Properties<\/strong><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Data from numerous plug analyses shows that the reservoir properties do not vary significantly across the field. Porosities typically range from 10 \u2013 15%. The effective permeability to oil ranges between 150 and 300 mD, although individual wells show values of up to 1300 mD (PRC 1990), which is obviously related to a certain degree of fractures in the reservoir (BERNHARD, GRUENWALD 1998). The net \/ gross ratio varies between 0.8 and 0.98.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2983399\"><\/a><a id=\"post-16046-_Toc3742478\"><\/a><strong>3.2 Analyses of Well H1<\/strong><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Well H1 is located in the western part of X field, it was spud on 11Jun2006 and completed on 21Aug 2006, Initial OWC was found at 12328ft-md-BDF while secondary OWC was encountered at 12258ft \u2013md \u2013BDF.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">The well found a net pay of 583ft of reservoir in the main oil zone of the Upper Gargaf Fm with an average porosity of 11.5% and 6.1% water saturation.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2983400\"><\/a><a id=\"post-16046-_Toc3742479\"><\/a><strong>3.2.1 TDS Technique<\/strong><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">TDS Technique used to analysis this well in two cases as following:<\/p>\n<ul dir=\"ltr\" style=\"text-align: justify;\">\n<li><strong>The unit slope line is observed (complete test).<\/strong><\/li>\n<\/ul>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (1): Prepare General Data Required for the Analysis. Table (1) introduces the required reservoir data<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2983195\"><\/a><a id=\"post-16046-_Toc3749203\"><\/a> Table (1): Input data for well H1<\/p>\n<table dir=\"ltr\">\n<tbody>\n<tr>\n<td>\n<p>STB\/day<\/p>\n<\/td>\n<td>\n<p>4087<\/p>\n<\/td>\n<td>\u00a0<\/td>\n<\/tr>\n<tr>\n<td>\n<p>Hr<\/p>\n<\/td>\n<td>\n<p>33.585<\/p>\n<\/td>\n<td>\u00a0<\/td>\n<\/tr>\n<tr>\n<td>\n<p>bbl\/STB<\/p>\n<\/td>\n<td>\n<p>1.6<\/p>\n<\/td>\n<td>\u00a0<\/td>\n<\/tr>\n<tr>\n<td>\n<p>Cp<\/p>\n<\/td>\n<td>\n<p>0.6<\/p>\n<\/td>\n<td>\u00a0<\/td>\n<\/tr>\n<tr>\n<td>\n<p>Psia<sup>-1<\/sup><\/p>\n<\/td>\n<td>\n<p>2.06<\/p>\n<\/td>\n<td>\u00a0<\/td>\n<\/tr>\n<tr>\n<td>\n<p>Ft<\/p>\n<\/td>\n<td>\n<p>460<\/p>\n<\/td>\n<td>\u00a0<\/td>\n<\/tr>\n<tr>\n<td>\n<p>Ft<\/p>\n<\/td>\n<td>\n<p>0.013283<\/p>\n<\/td>\n<td>\u00a0<\/td>\n<\/tr>\n<tr>\n<td>\n<p>Ft<\/p>\n<\/td>\n<td>\n<p>583<\/p>\n<\/td>\n<td>\u00a0<\/td>\n<\/tr>\n<tr>\n<td>\n<p>&#8211;<\/p>\n<\/td>\n<td>\n<p>0.115<\/p>\n<\/td>\n<td>\n<p>\u0278<\/p>\n<\/td>\n<\/tr>\n<\/tbody>\n<\/table>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (2): plot pressure versus time. (Fig.5) illustrate the change in pressure with time before and during the shut-in period for well H1.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><img loading=\"lazy\" decoding=\"async\" width=\"867\" height=\"425\" class=\"wp-image-16054\" src=\"http:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-5.png\" srcset=\"https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-5.png 867w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-5-300x147.png 300w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-5-768x376.png 768w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-5-18x9.png 18w\" sizes=\"auto, (max-width: 867px) 100vw, 867px\" \/><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2983454\"><\/a><a id=\"post-16046-_Toc3063569\"><\/a> Figure (5): Pressure vs time for well H1<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (3): Plot \u0394P and \u2206t\u00d7\u0394P\u2019 versus time on a log-log graph and \u0394t versus \u0394p on semi log graph for shut-in period. (Fig.6 &amp; 7) shows \u0394P and \u2206t\u00d7\u0394P\u2019 vs time and \u0394t vs \u0394p respectively for well H1.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><em><img loading=\"lazy\" decoding=\"async\" width=\"867\" height=\"458\" class=\"wp-image-16055\" src=\"http:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-6.png\" srcset=\"https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-6.png 867w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-6-300x158.png 300w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-6-768x406.png 768w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-6-18x10.png 18w\" sizes=\"auto, (max-width: 867px) 100vw, 867px\" \/><\/em><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2983455\"><\/a><a id=\"post-16046-_Toc3063570\"><\/a> Figure (6): Pressure drop and pressure derivative vs time for well H1<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">The unit slop line that used to calculate wellbore storage effect illustrated in this case (complete test), also the mid and late time regions are observed.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><em><img loading=\"lazy\" decoding=\"async\" width=\"867\" height=\"462\" class=\"wp-image-16056\" src=\"http:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-7.png\" srcset=\"https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-7.png 867w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-7-300x160.png 300w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-7-768x409.png 768w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-7-18x10.png 18w\" sizes=\"auto, (max-width: 867px) 100vw, 867px\" \/><\/em><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2983456\"><\/a><a id=\"post-16046-_Toc3063571\"><\/a> Figure (7): Pressure drop vs time for well H1<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (4): Draw the infinite-acting radial flow line. This line is of course horizontal. Read the value . As shown in (Fig.6).<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (5): Select any convenient time during infinite-acting radial flow line and read from the pressure curve. As shown in (Fig.6).<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (6): Draw the unit-slope line corresponding to the wellbore storage flow regime using early-time pressure and pressure derivative points. Read the coordinates of a point N on the unit-slope line: and . As shown in (Fig.6).<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (7): Calculate the WBS coefficient from Eq. (1)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (8): Calculate the permeability from Eq. (2)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">The permeability of this well is good.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (9): Calculate the skin factor from Eq. (3)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">In this case the value of skin factor mainly means that the well had a damage.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (10): Calculate pressure drop due to skin effect by using eq. (4)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (11): Select any convenient point from the late time data exhibited on the pseudo steady state flow line and read (\u2206P)<sub>pss<\/sub> = 309.54 and (\u2206t*\u2206P&#8217;)<sub>pss<\/sub> = 30.572 respectively, and calculate average reservoir pressure from eq. (5). The last pressure value, that is 3616.21 psi, is taken as P<sub>i.<\/sub><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (12): calculate flow efficiency from eq. (6).<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (13): calculate actual and theoretical Productivity Index from Eq. (7) and Eq. (8) respectively.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">The actual and theoretical productivity values are almost the same this indicates that the test analysis was good.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (14): calculate the distance from well to fault by using Eq. (12).<\/p>\n<ul dir=\"ltr\" style=\"text-align: justify;\">\n<li><strong>The unit slope line is not observed.<\/strong><\/li>\n<\/ul>\n<p dir=\"ltr\" style=\"text-align: justify;\">in this case the wellbore storage effect can be calculated by determining the coordinates of the maximum point (peak) on the \u2206t*\u2206p&#8217; versus time curve, i.e. \u2206t<sub>x<\/sub> and (\u2206t*\u2206p&#8217;)<sub>x<\/sub>, As shown in (Fig.8),.and then using eq. (9)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><em><img loading=\"lazy\" decoding=\"async\" width=\"864\" height=\"452\" class=\"wp-image-16057\" src=\"http:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-8.png\" srcset=\"https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-8.png 864w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-8-300x157.png 300w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-8-768x402.png 768w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-8-18x9.png 18w\" sizes=\"auto, (max-width: 864px) 100vw, 864px\" \/><\/em><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2983457\"><\/a><a id=\"post-16046-_Toc3063572\"><\/a> Figure (8) : Pressure drop and pressure derivative vs time for well H1<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">The value of wellbore storage effect obtained by Using the advantage of TDS technique (points from peak zone) gave a good result and approximately similar to that obtained in the case of unit slope line is observed.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u00a0<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><strong>3.3 Analyses of Well H2<\/strong><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Well H2 is proposed as s development well in the Upper Gargaf sandstone of the X Oil Field.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">The well was perforated by using TCP gun, HMX, 6shots\/ft, 60\u00b0 Phasing, 2.88&#8243; OD Omega Powerjet 2906. The perforation intervals from 11481\u2019 to 12110\u2019 md-bdf The initial Oil-Water Contact at 12,389 ft-md-bdf, secondary Oil-Water Contact at 12,260 ft-md-bdf, and reference depth is 12,150 ft-TVDSS.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">The well was brought on stream on 30th November 2009 and test run from 26th December 2009 to 2nd January 2010. Test production rates vary from 2245 bopd to 5192 bopd (36\/64\u201d to 64\/64\u201d) with a 0.2 \u2013 0.3 % water cut and without gas-lift.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2983403\"><\/a><a id=\"post-16046-_Toc3742482\"><\/a><strong>3.3.1 TDS Technique<\/strong><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">TDS Technique used to analysis this well in two cases as following:<\/p>\n<ul dir=\"ltr\" style=\"text-align: justify;\">\n<li><strong>The unit slope line is observed (complete test).<\/strong><\/li>\n<\/ul>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (1): Prepare General Data Required for the Analysis. Table (2) introduces the required reservoir data<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2983196\"><\/a><a id=\"post-16046-_Toc3749205\"><\/a> Table (2): Input data for well H2<\/p>\n<table dir=\"ltr\">\n<tbody>\n<tr>\n<td>\n<p>STB\/day<\/p>\n<\/td>\n<td>\n<p>5192<\/p>\n<\/td>\n<td>\u00a0<\/td>\n<\/tr>\n<tr>\n<td>\n<p>Hr<\/p>\n<\/td>\n<td>\n<p>67.502<\/p>\n<\/td>\n<td>\u00a0<\/td>\n<\/tr>\n<tr>\n<td>\n<p>bbl\/STB<\/p>\n<\/td>\n<td>\n<p>1.499<\/p>\n<\/td>\n<td>\u00a0<\/td>\n<\/tr>\n<tr>\n<td>\n<p>Cp<\/p>\n<\/td>\n<td>\n<p>0.38<\/p>\n<\/td>\n<td>\u00a0<\/td>\n<\/tr>\n<tr>\n<td>\n<p>Psia<sup>-1<\/sup><\/p>\n<\/td>\n<td>\n<p>1.708<\/p>\n<\/td>\n<td>\u00a0<\/td>\n<\/tr>\n<tr>\n<td>\n<p>Ft<\/p>\n<\/td>\n<td>\n<p>300<\/p>\n<\/td>\n<td>\u00a0<\/td>\n<\/tr>\n<tr>\n<td>\n<p>Ft<\/p>\n<\/td>\n<td>\n<p>0.25<\/p>\n<\/td>\n<td>\u00a0<\/td>\n<\/tr>\n<tr>\n<td>\n<p>Ft<\/p>\n<\/td>\n<td>\n<p>792<\/p>\n<\/td>\n<td>\u00a0<\/td>\n<\/tr>\n<tr>\n<td>\n<p>&#8211;<\/p>\n<\/td>\n<td>\n<p>0.129<\/p>\n<\/td>\n<td>\n<p>\u0278<\/p>\n<\/td>\n<\/tr>\n<\/tbody>\n<\/table>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (2): plot pressure versus time. (Fig.9) illustrate the change in pressure with time before and during the shut-in period for well H2.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><img loading=\"lazy\" decoding=\"async\" width=\"752\" height=\"452\" class=\"wp-image-16058\" src=\"http:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-9.png\" srcset=\"https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-9.png 752w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-9-300x180.png 300w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-9-18x12.png 18w\" sizes=\"auto, (max-width: 752px) 100vw, 752px\" \/><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2983461\"><\/a><a id=\"post-16046-_Toc3063576\"><\/a> Figure (9): Pressure vs time for well H2<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (3): Plot \u0394P and \u2206t\u00d7\u0394P\u2019 versus time on a log-log graph and \u0394t versus \u0394p on semi log graph for shut-in period. (Fig.10).and (Fig.11).shows \u0394P and \u2206t\u00d7\u0394P\u2019 vs time and \u0394t vs \u0394p respectively for well H2.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><em><img loading=\"lazy\" decoding=\"async\" width=\"1002\" height=\"525\" class=\"wp-image-16059\" src=\"http:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-10.png\" srcset=\"https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-10.png 1002w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-10-300x157.png 300w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-10-768x402.png 768w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-10-18x9.png 18w\" sizes=\"auto, (max-width: 1002px) 100vw, 1002px\" \/><\/em><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2983462\"><\/a><a id=\"post-16046-_Toc3063577\"><\/a> Figure (10): Pressure drop and pressure derivative vs time for well H2<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">The unit slop line that used to calculate wellbore storage effect illustrated in this case (complete test), also the mid and late time regions are observed.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><em><img loading=\"lazy\" decoding=\"async\" width=\"810\" height=\"424\" class=\"wp-image-16060\" src=\"http:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-11.png\" srcset=\"https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-11.png 810w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-11-300x157.png 300w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-11-768x402.png 768w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-11-18x9.png 18w\" sizes=\"auto, (max-width: 810px) 100vw, 810px\" \/><\/em><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2983463\"><\/a><a id=\"post-16046-_Toc3063578\"><\/a> Figure (11): Pressure drop vs time for well H2<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (4): Draw the infinite-acting radial flow line. This line is of course horizontal. Read the value . As shown in (Fig.10).<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (5): Select any convenient time during infinite-acting radial flow line and read from the pressure curve. As shown in (Fig.10).<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (6): Draw the unit-slope line corresponding to the wellbore storage flow regime using early-time pressure and pressure derivative points. Read the coordinates of a point N on the unit-slope line: and . As shown in (Fig.10).<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (7): Calculate the WBS coefficient from Eq. (1)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (8): Calculate the permeability from Eq. (2)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">The permeability resulted in this well is good.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (9): Calculate the skin factor from Eq. (3)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">In this case the value of skin factor mainly means that the well had a damage.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (10): Calculate pressure drop due to skin effect by using eq. (4)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (11): Select any convenient point from the late time data exhibited on the pseudo steady state flow line and read (\u2206P)<sub>pss<\/sub> =117.06 and (\u2206t*\u2206P&#8217;)<sub>pss <\/sub>= 14.239 respectively, and calculate average reservoir pressure from eq. (5). The last pressure value, that is 3292.44 psi, is taken as P<sub>i.<\/sub><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (12): calculate flow efficiency from eq. (6).<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (13): calculate actual and theoretical Productivity Index from Eq. (7) and Eq. (8) respectively.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">In this case, The actual and theoretical productivity values are not the same, and the reason may be due to uncertainty in average pressure value.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Step (14): calculate the distance from well to fault by using Eq. (12).<\/p>\n<ul dir=\"ltr\" style=\"text-align: justify;\">\n<li><strong>The unit slope line is not observed.<\/strong><\/li>\n<\/ul>\n<p dir=\"ltr\" style=\"text-align: justify;\">In this case, the wellbore storage effect can be calculated by determining the coordinates of the maximum point (peak) on the \u2206t*\u2206p&#8217; versus time curve, i.e. \u2206t<sub>x<\/sub> and (\u2206t*\u2206p&#8217;)<sub>x<\/sub>, As shown in (Fig.12)., and then using eq. (9)<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><img loading=\"lazy\" decoding=\"async\" width=\"1366\" height=\"768\" class=\"wp-image-16061\" src=\"http:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-12.png\" srcset=\"https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-12.png 1366w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-12-300x169.png 300w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-12-1024x576.png 1024w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-12-768x432.png 768w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-12-18x10.png 18w, https:\/\/www.hnjournal.net\/wp-content\/uploads\/2026\/03\/word-image-16046-12-135x75.png 135w\" sizes=\"auto, (max-width: 1366px) 100vw, 1366px\" \/><\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc2983464\"><\/a><a id=\"post-16046-_Toc3063579\"><\/a> Figure (12): Pressure drop and pressure derivative vs time for well H2<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">The value of wellbore storage effect obtained by using the advantage of TDS technique (points from peak zone) gave a good result and approximately close to that obtained in the case of unit slope line is observed.<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u00a0<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">The results were compared with the results from KAPPA software as shown in Table (3).<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">Table (3) : Summary of the results<\/p>\n<table dir=\"ltr\">\n<tbody>\n<tr>\n<td rowspan=\"2\">\n<p>Wells#<\/p>\n<\/td>\n<td rowspan=\"2\">\n<p>parameters<\/p>\n<\/td>\n<td colspan=\"2\">\n<p>TDS<\/p>\n<\/td>\n<td rowspan=\"2\">\n<p>KAPPA<\/p>\n<\/td>\n<\/tr>\n<tr>\n<td>\n<p>Complete test<\/p>\n<\/td>\n<td>\n<p>Test without unit slope line<\/p>\n<\/td>\n<\/tr>\n<tr>\n<td rowspan=\"5\">\n<p>H1<\/p>\n<\/td>\n<td>\n<p>C (bbl\/psi)<\/p>\n<\/td>\n<td>\n<p>0.055<\/p>\n<\/td>\n<td>\n<p>0.054<\/p>\n<\/td>\n<td>\n<p>0.05<\/p>\n<\/td>\n<\/tr>\n<tr>\n<td>\n<p>K (md)<\/p>\n<\/td>\n<td>\n<p>39.957<\/p>\n<\/td>\n<td>\n<p>&#8211;<\/p>\n<\/td>\n<td>\n<p>40.264<\/p>\n<\/td>\n<\/tr>\n<tr>\n<td>\n<p>S<\/p>\n<\/td>\n<td>\n<p>2.152<\/p>\n<\/td>\n<td>\n<p>&#8211;<\/p>\n<\/td>\n<td>\n<p>2.2<\/p>\n<\/td>\n<\/tr>\n<tr>\n<td>\n<p>\u0394P<sub>skin <\/sub>(psi)<\/p>\n<\/td>\n<td>\n<p>51.171<\/p>\n<\/td>\n<td>\n<p>&#8211;<\/p>\n<\/td>\n<td>\n<p>51.924<\/p>\n<\/td>\n<\/tr>\n<tr>\n<td>\n<p>(psi)<\/p>\n<\/td>\n<td>\n<p>3585.316<\/p>\n<\/td>\n<td>\n<p>&#8211;<\/p>\n<\/td>\n<td>\n<p>3585.91<\/p>\n<\/td>\n<\/tr>\n<tr>\n<td rowspan=\"5\">\n<p>H2<\/p>\n<\/td>\n<td>\n<p>C (bbl\/psi)<\/p>\n<\/td>\n<td>\n<p>0.1<\/p>\n<\/td>\n<td>\n<p>0.106<\/p>\n<\/td>\n<td>\n<p>0.09<\/p>\n<\/td>\n<\/tr>\n<tr>\n<td>\n<p>K (md)<\/p>\n<\/td>\n<td>\n<p>63.106<\/p>\n<\/td>\n<td>\n<p>&#8211;<\/p>\n<\/td>\n<td>\n<p>63.667<\/p>\n<\/td>\n<\/tr>\n<tr>\n<td>\n<p>S<\/p>\n<\/td>\n<td>\n<p>4.469<\/p>\n<\/td>\n<td>\n<p>&#8211;<\/p>\n<\/td>\n<td>\n<p>4.5<\/p>\n<\/td>\n<\/tr>\n<tr>\n<td>\n<p>\u0394P<sub>skin <\/sub>(psi)<\/p>\n<\/td>\n<td>\n<p>37.343<\/p>\n<\/td>\n<td>\n<p>&#8211;<\/p>\n<\/td>\n<td>\n<p>37.269<\/p>\n<\/td>\n<\/tr>\n<tr>\n<td>\n<p>(psi)<\/p>\n<\/td>\n<td>\n<p>3279.932<\/p>\n<\/td>\n<td>\n<p>&#8211;<\/p>\n<\/td>\n<td>\n<p>3258.24<\/p>\n<\/td>\n<\/tr>\n<\/tbody>\n<\/table>\n<h1 dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc3742487\"><\/a>4. Conclusion<\/h1>\n<ul dir=\"ltr\" style=\"text-align: justify;\">\n<li>TDS technique is particularly useful when the early-time unit slope line is not observed due to the lack of points or sever noise problem.<\/li>\n<li>In wells H1and H2 taking the coordinate points (, ) after maximum point of peak to give more accurate results.<\/li>\n<li>Another advantage of TDS technique that the wellbore storage effect can be estimating in the absent of the early time unite slope line and the hump.<\/li>\n<\/ul>\n<p dir=\"ltr\" style=\"text-align: justify;\"><a id=\"post-16046-_Toc3742490\"><\/a><strong>References<\/strong><\/p>\n<ol dir=\"ltr\" style=\"text-align: justify;\">\n<li>Tarek Ahmed, 2010. \u201cReservoir Engineering Handbook\u201d, 4th edition .<\/li>\n<li>Tiab, D., 1994. &#8220;Analysis of Pressure and Pressure Derivative without Matching: Vertically Fractured Wells in Closed Systems,&#8221; Journal of Petroleum Science and Engineering 11, 323.<\/li>\n<li>Tiab D., 1995. \u201cAnalysis of pressure and pressure derivative without type-curve matching: skin and wellbore storage\u201d. J Pet Sci Eng.<\/li>\n<li>Saleh, L., Traki, A., Alhaj, H., Gergab, M., Al-Osta, M., 2025 \u201cWell Test Interpretation with TDS Technique: Detection and Absence of Infinite Acting Radial Flow, Case Study\u201d <em>Alqalam Journal of Science, 207-216<\/em><\/li>\n<\/ol>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u00a0<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u00a0<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u00a0<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u00a0<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u00a0<\/p>\n<p dir=\"ltr\" style=\"text-align: justify;\">\u00a0<\/p>","protected":false},"excerpt":{"rendered":"<p>1. Introduction Well testing of oil and gas wells is carried out by changing production rate before shutting in the well while recording pressure throughout the entire time of test. [&hellip;]<\/p>\n","protected":false},"author":2,"featured_media":0,"parent":0,"menu_order":0,"comment_status":"closed","ping_status":"closed","template":"","meta":{"om_disable_all_campaigns":false,"_monsterinsights_skip_tracking":false,"_monsterinsights_sitenote_active":false,"_monsterinsights_sitenote_note":"","_monsterinsights_sitenote_category":0,"_joinchat":[],"footnotes":""},"class_list":["post-16046","page","type-page","status-publish","hentry"],"_links":{"self":[{"href":"https:\/\/www.hnjournal.net\/ar\/wp-json\/wp\/v2\/pages\/16046","targetHints":{"allow":["GET"]}}],"collection":[{"href":"https:\/\/www.hnjournal.net\/ar\/wp-json\/wp\/v2\/pages"}],"about":[{"href":"https:\/\/www.hnjournal.net\/ar\/wp-json\/wp\/v2\/types\/page"}],"author":[{"embeddable":true,"href":"https:\/\/www.hnjournal.net\/ar\/wp-json\/wp\/v2\/users\/2"}],"replies":[{"embeddable":true,"href":"https:\/\/www.hnjournal.net\/ar\/wp-json\/wp\/v2\/comments?post=16046"}],"version-history":[{"count":1,"href":"https:\/\/www.hnjournal.net\/ar\/wp-json\/wp\/v2\/pages\/16046\/revisions"}],"predecessor-version":[{"id":16068,"href":"https:\/\/www.hnjournal.net\/ar\/wp-json\/wp\/v2\/pages\/16046\/revisions\/16068"}],"wp:attachment":[{"href":"https:\/\/www.hnjournal.net\/ar\/wp-json\/wp\/v2\/media?parent=16046"}],"curies":[{"name":"wp","href":"https:\/\/api.w.org\/{rel}","templated":true}]}}