Technical Writing Examples

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Technical Writing Examples

  1. 1. Technical Writing Examples* OfCris Sleightholm*The examples are not in their entirety, merely a few pages of each.
  2. 2. Manual Title: Manual No.: Department: Marine Operations Procedure: Standard Tank Inspection Procedure for All UnitsIssue Date Revision No. Revision Date Prepared By Approved By Level No. Dec 16, 2010 1 Jan 6, 2011 1.0 PURPOSE This procedure identifies the standard methodology to which each Pride International operated Mobile Offshore Drilling Unit (MODU) shall be held when conducting inspection of tanks or void spaces. 2.0 SCOPE This procedure addresses only the visual inspection requirements for each tank and void space. This plan does not address non-destructive testing like hull thickness measurements. The requirements for hull thickness measurements are addressed in Pride International’s Standard Ultrasonic Testing Thickness Measurement Procedure. Comment [CS1]: Where will 3.4, 3.5 and 3.6 be documented? 3.0 GENERAL REQUIREMENTS Please indicate that you would like all 3.1 The requirements addressed in this plan shall be carried out in compliance with the items documented in Maximo Job applicable requirements of the Pride International Safety Management System (SMS) and Plans local laws and regulations. Comment [CS2]: Which ones are they responsible to be compliant to? 3.2 In preparation for any inspection, the tank or void space shall be opened, ventilated, and confirmed to be gas free prior to entry. 3.3 Each MODU shall have on board at least one copy of the Inspection Grading Criteria for the ABS Hull Inspection and Maintenance Program (HIMP) booklet to use as a reference Comment [CS3]: Where is the during visual tank inspections. For a copy of this booklet, please submit a request in document controlled (location)? Is this booklet electronic and is it created by writing to eroan@prideinternational.com. pride? If yes, then we can add it to the QSMS so it can be accessed 3.4 The coating shall be visually inspected using Table 2 in the Inspection Grading Criteria for the ABS Hull Inspection and Maintenance Program (HIMP) as a reference. The condition of the tank or void space shall be documented as meeting one of the following: 3.4.1 “GOOD” condition when there is only minor coating breakdown on the edge of stiffeners and no more than 10% general coating breakdown, Comment [CS4]: How do they assess the percentage? Is there some criteria? Or is it a general 3.4.2 “FAIR” condition when there is coating breakdown at the edge of stiffeners and estimation? weld connections or between 10% and 20% general coating breakdown, or 3.4.3 “POOR” condition when there is any hard scale or more than 20% general coating breakdown. 3.5 The steel plating and structures shall be visually inspected for corrosion using Table 3 and Table 4 in the Inspection Grading Criteria for the ABS Hull Inspection and Maintenance Program (HIMP) as a reference. The condition of the tank or void space shall be documented as meeting one of the following: 3.5.1 “GOOD” condition when there is no more than 20% light rusting, no hard scale, Comment [CS5]: How do they and no pits or grooves, assess the percentage? Is there some criteria? Or is it a general estimation?Uncontrolled When Printed Page 1 of 3 Steps to reviewing received document prior to formatting and editing: 1. Review and comment SMEs content 2. Return document to SME for review and answers and additional questions 3. Receive updated document from SME with satisfactory replies and input 4. Incorporate approved template organizational structure and styles 5. Track suggested changes, edits, deletions 6. Return to SME for approvals and comments 7. Submit finalized document to QA for final approval.
  3. 3. Manual Title: Manual No.: Department: Marine Operations Procedure: Standard Tank Inspection Procedure for All UnitsIssue Date Revision No. Revision Date Prepared By Approved By Level No. Dec 16, 2010 1 Jan 6, 2011 3.5.2 “FAIR” condition when there is 20% or more light rusting, less than 10% hard scale, or pits or grooves with depths less than one-third the original steel thickness, or 3.5.3 “POOR” condition when there is 10% or more hard scale or pits or grooves with depths one-third or more the original steel thickness. 3.6 The tank or void space shall be visually inspected for cleanliness using Table 7 in the Inspection Grading Criteria for the ABS Hull Inspection and Maintenance Program (HIMP) as a reference. The condition of the tank or void space shall be documented as meeting one of the following: 3.6.1 “GOOD” condition when there is no more than a light layer of residue and cleaning is not required for visual inspection of the coating and steel, 3.6.2 “FAIR” condition when there is loose scale, water, dirt, sediment, or other residues and local cleaning is required for visual inspection of the coating and steel, or 3.6.3 “POOR” condition when there is scale, water, dirt, sediment, or other residue that does not give access to the surface and visual inspection of the coating and steel is not possible without specialized cleaning tools or personnel. Comment [CS6]: Will results be documented and where? 3.7 The tank or void space shall be visually inspected for deformations, cracks, and other Comment [CS7]: Which standards? structural damages. The same requirements in this document? Will results be documented and 3.8 Each access ladder shall be visually inspected to the same standards as the tank or void where? in which they are located. Indicate that you are referencing the standards in sections 3.4, 3.5 and 3.6 3.9 Each pipe passing through the tank or void shall be visually inspected for coating Comment [CS8]: Will results be breakdown and corrosion. Each pipe penetration through a water tight boundary and documented and where? each area of bottom plating under a suction bellmouth, including any wear plating, shall Comment [CS9]: Will results be be inspected. documented and where? Comment [CS10]: Will results be documented and where? 3.10 Each deck penetration shall be visually inspected for corrosion. Comment [CS11]: What determines good condition as opposed to fair or 3.11 Each vent line shall be visually inspected for corrosion and proper labeling. The inner poor? In this case is it operable check valve or ball shall be operationally tested to ensure it is in good condition. (good) or inoperable (poor) Will results be documented and 3.12 Each manhole cover shall be visually inspected for corrosion and proper labeling. Each where? manhole and associated gaskets, nuts, and bolts shall be visually inspected for corrosion Revise this term good, I suggest testing for operability or inoperability or wear. Comment [CS12]: What determines good condition as opposed to fair or 3.13 Each sounding pipe shall be visually inspected for corrosion and operationally tested to poor? In this case is it operable ensure that it is clear from obstructions. The area of bottom plating under the opening (good) or inoperable (poor) (striker plate) shall be visually inspected to ensure it is in good condition. Will results be documented and where? 3.14 If a liquid level sensor or alarm is installed, it shall be operationally tested and calibrated. Comment [CS13]: Will results be documented and where?Uncontrolled When Printed Page 2 of 3
  4. 4. Manual Title: Manual No.: Department: Marine Operations Procedure: Standard Tank Inspection Procedure for All UnitsIssue Date Revision No. Revision Date Prepared By Approved By Level No. Dec 16, 2010 1 Jan 6, 2011 3.15 Each overboard discharge valve shall be visually inspected for corrosion and operationally tested if practical. Comment [CS14]: Will results be documented and where? 3.16 Each sacrificial anode shall be visually inspected to ensure at least 40% of the original They have the option to not test anode material remains in place. Each anode with less than 40% of its original material operationally. Minimum they must visually inspect? remaining shall be replaced. If the depletion percentage of the anode cannot be Consider rewording. As it is currently determined, it shall be replaced. stated, you are communicating that the responsible person has the option of performing this requirement. 3.17 For jack-ups, the drain plug shall be removed, visually inspected for corrosion, Please indicate if they can not operationally tested to ensure it is in good condition, and repaired as necessary. Prior to perform this action then what action completing this procedure, it shall be confirmed that the drain plug is reattached, properly are they required to perform. Should they have divers go and inspect? operating, and placed in its normal operating condition. Comment [CS15]: How do they assess the percentage? Is there some criteria? Or is it a general estimation? For technical audit purposes, how will one determine 40%? Is there criteria or is it a guess? How will they determine when there is 40 or 45% remaining. I suggest: stating that an anode will be replaced when more than half of the material has deteriorated. Will results be documented and where? Comment [CS16]: Will results be documented and where?Uncontrolled When Printed Page 3 of 3
  5. 5. EXAMPLE OF SPECIFICATION PROCEDURE W/STRUCTURED DOCUMENT ORGANIZATIONAND STYLES Manual Title: xxxxxxxxxxxx Manual No.: xxxxxxxxxxx Department: Asset Management & Engineering Specification: xxxxx-Drill Pipe Purchase 5” OD, 19.50 ppf, S135, API NC50 (6⅝” OD x 2¾” ID) Issue Date Revision No. Revision Date Prepared By Approved By Level No. 01 Mar 2011 0 2 1.0 PURPOSE The Drill Pipe Purchase 5” OD, 19.50 ppf, S135, API NC50 (6⅝” OD x 2¾” ID) Specification provides the requirements for the manufacturing, inspection, testing, and preparation of the drill pipe. 2.0 SCOPE The specification applies to Pride’s fleet operations worldwide. 3.0 DEFINITIONS AND ACRONYMS • AISI – American Iron and Steel Institute • HWDP – Heavy Weight Drill Pipe • ID – Inner Diameter • OD – Outer Diameter • PCP – Process Control Plan • QA – Quality Assurance 4.0 RESPONSIBILITIES • Corporate engineer tubular management team – is required to review, maintain, update and implement the requirements in this document. 5.0 DRILL PIPE SPECIFICATIONS Drill pipe features and description are listed in the table below. Drill Pipe Feature Descriptions Drill Pipe Nominal Diameter 5-inch Outer Diameter Tube Steel Material Grade API Spec 5DP, Grade S, 135 ksi min. yield strength Total Length – Required Minimum See Purchase Order for min. footage length; Acceptable Footage Tolerance Plus up to 3% maximum overage in total length. Drill Pipe Joint Nominal Length, or Range 31 ft, Range 2 Acceptable Length Variance 30.5 ft minimum length, 31.5 ft maximum length 19.50 lbs per foot, 0.362” nominal wall thickness Nominal Weight Schedule / Wall Thickness Minimum wall thickness is 95.0% of the nominal wall thickness; Acceptable Minimum Wall Thickness i.e., greater than or equal to 0.344 inch. Tool Joint Steel Material API Spec 5DP requirements, with 120 ksi minimum yield strength Tool Joint Outside Taper at Box / Pin 18-degree at box end/35-degree at pin end API NC50, with approved Re-Facing Benchmarks. (NOV-GPDS X- Tool Joint Rotary Shouldered Connection Mark, or equivalent) Tool joint OD / Tool joint ID 6.625” OD/2.750” ID Acceptable Dimensional Tolerance API Spec 5DP for OD & ID dimensional tolerance Minimum Tool Joint OD Length 14” @ box end/11” @ pin end. (API min. + 4 in.) Tool Joint Hardfacing Material Tuboscope TCS-Titanium or approved equivalent Hardfacing Size & Location 4 inch at Box End only, raised (proud) hardband Thread Protectors Drilltec TJP series composite resin material or equivalent Internal Plastic Coating Tuboscope TK34XT or approved equivalent Pride Drill Pipe Serial Numbers See Purchase Order for Serial Number Listing Uncontrolled When Printed Page 1 of 13
  6. 6. Manual Title: xxxxxxxxxxxx Manual No.: xxxxxxxxxxx Department: Asset Management & Engineering Specification: xxxxx-Drill Pipe Purchase 5” OD, 19.50 ppf, S135, API NC50 (6⅝” OD x 2¾” ID) Issue Date Revision No. Revision Date Prepared By Approved By Level No. 01 Mar 2011 0 25.1 Plan review and approvalPride shall receive, and review the manufacturer’s process control plan (PCP) prior to commencingmanufacturing drilling tubulars for Pride. The PCP shall cover all required production processes, inspections,destructive and non-destructive tests, and relevant technical controls, to be performed by the manufacturerthroughout the manufacturing processes to ensure the product consistency and compliance with the purchaseorder requirements. Pre-production meetings between Pride and manufacturing quality assurance (QA) staffare required to facilitate the information exchange, and to establish an efficient working arrangement betweenPride and the manufacturer to accomplish the purchase order contract compliance.5.2 Deviation and concessionsAll deviations, discrepancies, concessions, and exceptions to this specification or referenced specificationsshall be submitted to Pride in writing for review and approval. No alterations to the requirements shall beimplemented without written approval from Pride.5.3 Access to manufacturing facilities and surveillancePride’s representatives shall have reasonable access to the manufacturing facilities at all times while drillingtubular specified on the purchase order contract is being manufactured, tested and inspected. The requiredtests, inspections, and identified surveillance activities are listed in the tables following:5.3.1 Required tests for new drill pipes Table 1 Required tests for new drill pipes Tests Drill Pipe Tube Body Tool Joint Weld Zone1 Chemistry API Spec 5DP requirements API Spec 5DP requirements Test Frequency: One per heat Test Frequency: One per heat per lot per lot2 Tensile Strength API Spec 5DP requirements Per API Spec 5DP Tensile Yield Strength (see note 2 (see note 2 & Minimum 135 –165 ksi yield Minimum 120-165 ksi yield strength below) note 3 below) strength Minimum 145 ksi tensile strength Test Frequency: σy – minimum Minimum 145 ksi tensile strength Test Frequency: One per lot or every 200 welds, yield strength Test Frequency: One pin/heat/lot or 100 pins, whichever is lower σt– minimum Drill pipes - One per heat per lot, whichever is lower. tensile strength or one per each 100 joints, Wherever practicable, One whichever is less box/heat/per lot or 100 boxes, whichever is lower.3 Surface Hardness 285 ≤ HBW ≤ 341 HRC ≤ 37 max. Test Frequency: all tool joints Test Frequency: all welds4 Through Wall API Spec 5DP, PSL-3 Per API Spec 5DP Hardness 285≤BHN≤341 HRC ≤ 37 max. Test Frequency: Test Frequency: One pin per heat per lot or 100 pins, One per lot or every 200 welds, whichever is lower. whichever is lower. One box per heat per lot or 100 boxes, whichever is lower.Uncontrolled When Printed Page 2 of 13
  7. 7. Manual Title: xxxxxxxxxxxx Manual No.: xxxxxxxxxxx Department: Asset Management & Engineering Specification: xxxxx-Drill Pipe Purchase 5” OD, 19.50 ppf, S135, API NC50 (6⅝” OD x 2¾” ID) Issue Date Revision No. Revision Date Prepared By Approved By Level No. 01 Mar 2011 0 2 Tests Drill Pipe Tube Body Tool Joint Weld Zone5 Charpy V-Notch API Spec 5DP SR20 API Spec 5DP SR20 API Spec 5DP SR20 modified.. (energy unit: ft- S135 grade DP, 30/22 @ 14 ±5 120 ksi grade TJ, 30/22 @ 14 ±5 Across weld 30/22 @14 ±5 degF lbs) degF degF Test Frequency: (see note 1 & Test Frequency: Test Frequency: Same as tensile test note 3 below) Same as tensile test Same as tensile test6 Transverse Side All Grades: Per API Spec 5DP Bend Test Test Frequency: One (1) per lot (see note 3 or every 400 welds, whichever is below) lower, each test consists of at least 2 specimens.Note 1: The test data 30/22 @ 14 ±5 degF represents a minimum average test value of 30 ft-lbs (41 J), with acorresponding minimum individual test value of 22 ft-lbs (30 J), out of a total of 3 Charpy V-notch specimenstested at the 14 ºF, +/-5 ºF (or -10ºC, +/-2.8 ºC). Test specimens referenced herein are full size10 mm x 10mm unless otherwise specified.Note 2: Tensile yield strength across weld zone shall be at least 10% higher than pipe body tensile yieldstrength; i.e.,(σy-weld x Aw) ≥ 110% x (σy-tube x Atube). Validation of tensile yield strength design by calculationshall be provided to validate TJ OD & ID design across weld zone.Note 3: Retests shall be per Specification for Drill Pipe.5.3.2 Required inspections for new drilling tubular Table 2 Required inspections for new drilling tubular Components Inspection Drill Pipe1. Pipe body or Round Stocka. Visual Requiredb. EMI (for W.T.≤0.350”) Applicablec. FLUT (Internal Flaw & Thickness) Requiredd. Straightness Requirede. Dimensional Data (OD, OD tolerance) Required2. Pipe ends & upsetsa. Visual Requiredb. WMPI End Area Requiredc. Ovality Requiredd. Internal Upset Transition length, Miu Requirede. Concentricity Required3. Rotary Shoulder Connections (Toll Joints)a. Visual Requiredb. WMPI RequiredUncontrolled When Printed Page 3 of 13
  8. 8. EXAMPLE OF WORD FORM WITH EXPANDING FIELDS Manual Title: xxxxxxxxxxxx Manual No.: xxxxxxxxxxx Department: xxxxxxxxxxxxx Procedure.: Management of Change Form Issue Date Revision No. Revision Date Prepared By Approved By Level No. Management of Change – Part 1 For help/explanation of text to be entered, click on text form field and press F1. Facility: Date: Equipment People Process Type of Change Temporary Permanent Rig MOC Identifier: Change Requester: Brief Description of Change Justification for the Change Identify Risk – People, Process, Equipment Proposed Measures to Mitigate Risk Basic Steps for Implementation Initial Approval OIM/Change Manager: Date Approved & Sent: Rig Performance Manager/Change Approver: Date Reviewed: Comments: Approved as Submitted: Approved with Required Changes: Cancelled: Uncontrolled When Printed Page 1 of 3
  9. 9. Manual Title: xxxxxxxxxxxx Manual No.: xxxxxxxxxxx Department: xxxxxxxxxxxxx Procedure.: Management of Change Form Issue Date Revision No. Revision Date Prepared By Approved By Level No. Part 2 Do not complete this section until initial base approval received. Implementation – To be completed by change requester Action By who 1) 2) 3) 4) 5) 6) 7) 8) 9) 10) 11) 12) 13) 14) 15) 16) 17) 18)  Approval OIM – Change Manager: Date Approved & Sent: QHSE Mgr – Change Verifier: Date Reviewed: Required Discipline Authority: Required Discipline Authority: Required Discipline Authority: Required Discipline Authority: Rig Performance Manager – Change Approver: Date Approved: Uncontrolled When Printed Page 2 of 3
  10. 10. Equipment Failure Reporting and Investigation Process Anyone TC RAM RPM / OIM CAM Corporate 1 2 Equipment Begin Evidence Failure Collection EXAMPLE OF FLOW PROCESS CREATED IN VISIO Identified (Preservation) Process 3 Create CM Order in Maximo per 03- 05-Maximo-07 Procedure 4 5 Notify Pride Notify Regulatory/Class Management Per Agencies as Required Notification Table or if Class is Affected 6 End Yes Perform Investigation? See Matrix for Guidance 8 No Perform Investigation No and Draft Report 7 11 Send Email to Yes Equipment Failure Alert Required to Reports Email on Other 9 Investigation Decision Rigs? Review Investigation with RAM, CAM and RPM/OIM and Develop Action Items 10 12 Finalize Report and Review Summaries with Summary and Send to Corporate Technical and Equipment Failure Management Teams Reports Email 13 Yes Follow Up Required? 14 No Send Summary to Alerts, Advisories, and Bulletins Process (Tech- 03 Appendix C) for Distribution/Sharing 15 Update Action Item Tracking System 16 Performance Monitoring
  11. 11. Change Authorization Technical Expertise (CATE) Process Original (Rig, Shore-based, Shore-based Ops AME Corp Rig Corporate) Need identified for asset Rig Asset Manager and rig CATE administrator assigns to Primary modification or completes CATE form Person in Charge (PIC) technical expertise CATE reviewed by: Rig Asset Mgr, Rig CATE administrator notifies originator Performance Mgr, Country Asset Mgr. Originator and rig asset manager of receipt and of submits form to Unapproved - CATE sent back to primary PIC carrying out work Rig Asset originator for revision, or cancelled. Manager Determine if CATE impacts client contract. If yes, Rig Performance Mgr notify customer of proposed changes, impacts, and determine any required CATE reviewed by primary PIC resolution. Approved - Rig Asset Manager logs CATE submittal and issues rig specific CATE number (# format: RIG-CATE-001). Yes Multiple CATE disciplines approved? required? CATE and supporting documentation No submitted to CATE mailbox Primary PIC No Yes completes request CATE review committee reviews submittals; assigns secondary PIC for multi-discipline submittals, approves completed request and verifies cancelled request Final status is received: Rig Asset Manager coordinates follow- CATE administrator notifies final status up activities. to Originator, Rig Asset Manager, and If Rig Asset Mgr decides not to execute Country Asset Manager an approved CATE, the CATE administer will be notified. Equipment modification/ change completed; rig notifies Rig Rig Asset Mgr verifies execution of Asset Mgr CATE in compliance with defined CATE requirements and completes CATE administrator submits Close Out close-out section of CATE form and form and documentations to Primary forwards to CATE administrator. PIC Rig Asset Mgr notifies Rig Equipment List Owner of changes made where Primary PIC completes changes to applicable. O&M, job plans, dwgs, etc. Primary PIC notifies CATE administrator when final documentation completed CATE closed
  12. 12. EXAMPLE OF PROCEDURE INCORPORATING SCREEN SHOTS Manual Title: Quality Management Manual Manual No.: Pride-01-08-AME Department: Asset Management & Engineering Procedure.: Tech xx Lube Sample Print & Ship Instr. Issue Date Revision No. Revision Date Prepared By Approved By Level No.1.0 SAMPLE LUBRICANT PRINT LABEL INSTRUCTIONSThe first day of each month, or as soon as possible thereafter, the rig technical coordinator (TC) shall accessthe Pride Oil Analysis webpage to print identifying labels for the lubricant and subsea samples that arerequired. Note: Print one set of labels for the bottles, and one set to go on the outside of the second plasticbag in which the filled sample will be placed.The labels should be verified by referring to the preventive maintenance requirement that is linked to theSampling Routine and Subsea Equipment spreadsheet.• Once the sample labels are printed and filled-out, the TC shall provide the labels and clean sample bottles to the rig personnel assigned to extract the lubricant or subsea fluid samples.• Sample bottles shall be filled to 3/4 capacity with the correct labels affixed to each bottle. A second label is placed on the outside of the second bag in case the jar leaks.• All completed sample bottles placed in the second new plastic bag and returned to the TC for shipment to the lab.• The MAXIMO work order must be completed as directed in the job plan.1.1 Printing Sample Bottle Labels (First Time Users)1. Ensure the computer used for printing labels is attached (cable) to the DYMO printer prior to logging in.2. Navigate to the Lubricant Analysis website: http://prideinternational.als.com.au/ and login with your username and password. Note: If you do not have your login and password, contact oilanalysis@prideinternational.com Note: Detailed training will be available at a later date. Additional functions will also be added in the future.Uncontrolled When Printed Page 1 of 13
  13. 13. Manual Title: Quality Management Manual Manual No.: Pride-01-08-AME Department: Asset Management & Engineering Procedure.: Tech xx Lube Sample Print & Ship Instr. Issue Date Revision No. Revision Date Prepared By Approved By Level No.3. Setting default printer. • It is suggested to set the label printer as the default printer when printing labels. • Typically, the DYMO 450 label writer is used with DYMO #30323 size labels. • If there are problems printing the labels, email: oilanalysis@prideinternational.com to send a detailed description of the problem.4. To access online help, press F1 key for on-line help and a down-loadable PDF help file that explains all the functions available on the website.Uncontrolled When Printed Page 2 of 13
  14. 14. Manual Title: Quality Management Manual Manual No.: Pride-01-08-AME Department: Asset Management & Engineering Procedure.: Tech xx Lube Sample Print & Ship Instr. Issue Date Revision No. Revision Date Prepared By Approved By Level No.5. Click on Samples from the menu bar.6. Click on Sample Submission from the drop down list.7. A list of all the compartments that are in the oil analysis program is displayed. Note: In the second column labeled Compartment Serial No., the scheduled interval for taking samples is indicated: Monthly, Quarterly, Semi-annually, and Annually.Uncontrolled When Printed Page 3 of 13
  15. 15. EXAMPLE OF SCIENTIFIC REPORT FOR THE DEPARTMENT OF ENERGYSpr Expansion Conceptual Design ReportChacahoula Site, LA 3.0 GEOLOGY OF CHACAHOULA SALT DOME3.1 REGIONAL GEOLOGY Salt domes within the Gulf Coast occur in two regions: a northern belt through northernLouisiana and Mississippi and a southern belt along the Gulf Coast and offshore. TheChacahoula salt dome is located within the Coastal Salt Dome Province of Louisiana. In thisarea, active sedimentation and subsidence has been occurring since the Mesozoic Era, resultingin up to 30,000 feet of silt, sand, shale, and evaporites. During the Jurassic and early Cretaceous,these evaporates were overlain by clastic and carbonate rocks deposited during alternating cyclesof marine transgressions and regressions. During the Cenozoic Era (70 million years to present),large amounts of sediment were deposited in the Gulf Coast Basin and subsidence continuesunder the accumulated weight of the sediment overburden. The first movement of the Louann Salt probably occurred in either the late-Jurassic or theCretaceous. As the basin subsided, salt movement was probably initiated when the salt wasburied under a sufficiently large amount of sediment. Once salt movement commenced, the saltwould tend to form diapiric structures, such as salt ridges and salt domes where salt was buriedunder a sufficiently large amount of sediment. Except around salt domes, regional faulting in theGulf Coast generally consists of large-scale, east-west trending, down to the basin (south),normal faults. These faults generally parallel the Gulf Coast, and since sediment thickness mayincrease dramatically on the downthrown side, they are frequently referred to as “growth faults.”These faults usually are listric and usually have a dip of approximately 45 to 50° in the uppersections and tend to flatten with depth. Chacahoula dome is within the Gulf Coast geosynclines, characterized locally up to 40,000’of Miocene and younger unconsolidated-to-poorly consolidated sediments. These sediments areprincipally composed of sands and shales. The dome is situated just north of the east-westMiocene age geosynclinial axis and slightly west of the arcuate noth-south trending Mississippistructural trough. A series of normal gravity faults, trending slightly northeastward, control the region’ssubsurface structure. This faulting, attributed to progressive subsidence of the depositionalbasin, is roughly parallel to the Gulf Coast geosynclinial axis and is downthrown to the south.Task 11 - Chacahoula Draft Report_Cris.doc 10
  16. 16. Spr Expansion Conceptual Design ReportChacahoula Site, LA3.2 TOP OF SALT Because it lies relatively close to the surface, the Chacahoula salt mass is classified as ashallow dome. Lying within the Texas-Louisiana salt dome belt, it is elliptically shapedstructure with a rather flat top and steep sides. The location and top of salt maps are shown inFigures 3-1 and 3-2, respectively. Near the top of salt, at an elevation of -3,000’, the east-westaxis is about three miles long; while, at a depth of about -15,000’, the long east-west axis jumpsto about 4.2 miles. The shallowest known salt occurrence was encountered near the center ofSection 72 at a depth of -1,100’ and is an isolated high point. The area enclosed within the -2,000’ contour is approximately 2 square miles while the area enclosed by the -3,000’ contourappears to contain a little over 3 square miles. Quality of salt mass is largely unknown at thistime. However, disseminated anhydrite is probably present in amounts of perhaps 3 to 7 percent.Table 3-1 shows a data sheet of the dome. Chacahoula Dome Figure 3-1. Chacahoula Salt Dome Location MapTask 11 - Chacahoula Draft Report_Cris.doc 11
  17. 17. EXAMPLE OF INSTALLATION PROCEDURE W/DRAWINGS QUICK CONNECTORS INCORPORATED P5000 PENETRATOR INSTALLATION PROCEDURE: S-63 Generic For Flat Leaded Pump Cable REV. A PAGE 1 OF 27 APPROVED: DATE: 04/17/071. System Overview© 2007 - QUICK CONNECTORS INCORPORATED
  18. 18. QUICK CONNECTORS INCORPORATED P5000 PENETRATOR INSTALLATION PROCEDURE: S-63 Generic For Flat Leaded Pump Cable REV. A PAGE 2 OF 272. Bottom Seal Installation A. Install the tubing hanger and landing joint into the string. B. Remove a Bottom Seal Fitting (Swagelok) from one of the Penetrator Assemblies. C. Remove the nut from the body portion of the fitting. Ensure that the two ferrules are installed correctly, as shown. D. Wrap Teflon tape on the 3/8” NPT pipe threads of the fitting. E. Apply anti-seize compound to the straight threads of the fitting. F. Reinstall the nut onto the body portion of the fitting. G. Starting with the middle port, use an 11/16” wrench to tighten the body portion of the Bottom Seal Fitting into the bottom of the tubing hanger. H. DO NOT tighten the Swagelok nut at this time. I. Repeat the above for the other 2 fittings.© 2007 - QUICK CONNECTORS INCORPORATED
  19. 19. QUICK CONNECTORS INCORPORATED P5000 PENETRATOR INSTALLATION PROCEDURE: S-63 Generic For Flat Leaded Pump Cable REV. A PAGE 3 OF 273. Penetrator Installation A. Push a Penetrator up through the tubing hanger so that the distance from the top of the 3/8” Penetrator tube to the top of the tubing hanger (at the 3/8” NPT ports) is exactly X”. X” = Gage Distance. This distance can vary depending on the wellhead dimensions. It is provided by QCI to allow 1-3/4” of Penetrator tubing to protrude up above the Tubing Head Adaptor after the adaptor is tightened to the Tubing Head. SEE NEXT PROCEDURE FOR GAGE DISTANCE CALCULATION. The 3/8” Tube Bending Pliers can be used to temporarily hold the Penetrator in place while the Swagelok nut is tightened. B. Tighten the nut on the Bottom Seal fitting 1-1/2 turns past hand tight. This will lock the Penetrator in place and seal it. Place a mark on the Swagelok Nut and body to ensure the correct number of turns. C. Repeat this procedure for the remaining Penetrators.© 2007 - QUICK CONNECTORS INCORPORATED
  20. 20. EXAMPLE OF HS&E POLICY PROCEDUREPB ESS, INC. Health Safety & Environmental ManualTitle: Section SP 6.02 Revision 02.1Abrasive Wheels Page Page 1 of 4 Effective Date 02/16/07 Supersedes 11/01/021.0 STORAGE AND HANDLING A. Immediately after unpacking, all abrasive wheels shall be closely inspected to ensure they have not been damaged during shipping or handling. If there is visible damage to the shipping container, special care must be taken in inspection of wheels. B. Prior to storage, each wheel shall be given the “ring test”. For this test, small wheels may be supported on the mounting hole by a pin or one finger, and tapped lightly with a nonmetallic instrument (screwdriver handle, etc.) at a point approximately 45° to either side of the vertical centerline of the wheel and one to two inches from the outer edge. Large wheels may be stood upright on a clean, hard floor for this test. Wheels must be dry, clean, and free of sawdust of packing material for this test. A “dead” sound indicates a crack or damage to the wheel and it shall not be stored for use. C. Wheels shall be stored in a dry area where they are not subjected to extreme temperature changes. Storage rack or area shall be protected from excessive vibration or possibility of physical damage to wheels. D. Wheels shall be stored in racks, bins, or drawers in an orderly and safe manner facilitating wheel selection with minimum handling. E. Straight or tapered wheels of appreciable thickness shall be stored on edge in racks; two- point support shall be provided to prevent rolling. Frequent partitions allow wheels to be withdrawn without causing tipping of others in rack. F. Thick, organic bonded (cutting-off) wheels shall be laid flat on a flat, horizontal surface to prevent warping. No separating material shall be placed between stacked thin wheels. G. Large wheels may be stacked on a horizontal surface with cushioning material between wheels. H. Small cup wheels and special shapes may be stored in containers or bins. I. Great care shall be used in handling wheels to prevent damage. The following rules shall always be followed: i. Handle wheels carefully to prevent dropping, bumping, or exposure to moisture. ii. No wheel shall be rolled hoop-fashion. iii. Use trucks or other mechanical means to transport wheels too large for manual handling.2.0 INSTALLATION A. All abrasive wheels shall be closely inspected and given ring test immediately prior to mounting to insure freedom from cracks, or damage in storage and handling. B. The rated operating speed of wheel shall be checked before mounting and must be equal to or exceed to spindle speed of machine. Diameter of wheel shall not exceed that recommended by machine manufacturer.ISSUED BY: President, PB Energy Storage Services, Inc. 11757 Katy Freeway, Suite 600 Houston, TX 77079 Ph: 281.496.5590 Fax: 281.589.5865
  21. 21. PB ESS, INC. Health Safety & Environmental ManualTitle: Section SP 6.02 Revision 02.1Abrasive Wheels Page Page 2 of 4 Effective Date 02/16/07 Supersedes 11/01/02 C. Wheel shall fit easily on spindle; spindle diameter shall not be more then .002” under standard size. This easy fit assures safety clearance under operating conditions. If a bushing is used, it shall not exceed width of wheel and shall not contact flanges. D. Surface contacts of wheels, wheel blotters, and required flanges shall be flat and free of foreign matter. E. Required blotters shall cover entire area of wheel flanges; blotter thickness should not exceed .025”. F. Wheels shall be mounted between flanges, which shall not be less than one-third the diameter of the wheel. EXCEPTIONS: “Mounted wheels, portable wheels with threaded inserts or projecting studs, abrasive discs (inserted nut or washer, projecting stud type), plate mounted wheels, cylinder, cup or segmental wheels that are mounted in chucks, and special wheels using adapters instead of flanges). G. Flanges shall be of appropriate material (safety flanges of steel, other flanges of cast iron, steel or other material of equal or greater strength and rigidity), dimensionally accurate, of same diameter with equal bearing surface. H. Spindle and nut on single and nut mountings shall be tightened only sufficiently to drive the wheel and prevent slippage. Multiple screw flanges shall be tightened uniformly in a criss-cross manner to 15-20 foot-pounds to insure even distribution of pressure over flanged surfaces. I. Bench and pedestal mounted wheels shall have: a. Machine secured to bench or floor. b. Tool rest adjusted within 1/8” of wheel. c. Tongue adjusted within 1/4” of wheel. d. Substantial guard that exposes no more than 90° of edge and side of wheel. (Guards on wire wheels shall expose no more than 180° of work surface.) e. Frame grounded either through 3-wire grounded cord or external grounding. J. Portable grinding wheels: a. Cup-type grinder shall be equipped with guard that encloses wheel sides to 1/3 of wheel thickness. b. Right-angle or vertical grinders shall be equipped with a guard giving a maximum of 180° of wheel exposure, and located between operator and wheel during work. c. Other types of portable grinders shall have guard-limiting exposure on periphery and sides of wheel to 180° with top half always enclosed. d. Small pencil grinders with factory-mounted wheels are exempt from the above.ISSUED BY: President, PB Energy Storage Services, Inc. 11757 Katy Freeway, Suite 600 Houston, TX 77079 Ph: 281.496.5590 Fax: 281.589.5865

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