Technical Writing Examples

Technical
Writing
Examples*
Of

Cris Sleightholm
*The examples are not in their entirety,
merely a few pages of each.

Manual Title:
Manual No.:
Department: Marine Operations
Procedure: Standard Tank Inspection Procedure for All
Units
Issue 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
estimation?

Uncontrolled When Printed Page 1 of 3

Steps to reviewing received document prior to formatting and editing:
1. Review and comment SME's 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.

Manual Title:
Manual No.:
Units
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?
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)

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.
where?
3.14 If a liquid level sensor or alarm is installed, it shall be operationally tested and calibrated. Comment [CS13]: Will results be

Manual Title:
Manual No.:
Units
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

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
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.

where?


EXAMPLE OF SPECIFICATION PROCEDURE W/STRUCTURED DOCUMENT ORGANIZATION
AND 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)

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




5” OD, 19.50 ppf, S135, API NC50
(6⅝” OD x 2¾” ID)

01 Mar 2011 0 2

5.1 Plan review and approval
Pride shall receive, and review the manufacturer’s process control plan (PCP) prior to commencing
manufacturing 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 manufacturer
throughout the manufacturing processes to ensure the product consistency and compliance with the purchase
order requirements. Pre-production meetings between Pride and manufacturing quality assurance (QA) staff
are required to facilitate the information exchange, and to establish an efficient working arrangement between
Pride and the manufacturer to accomplish the purchase order contract compliance.

5.2 Deviation and concessions
All deviations, discrepancies, concessions, and exceptions to this specification or referenced specifications
shall be submitted to Pride in writing for review and approval. No alterations to the requirements shall be
implemented without written approval from Pride.

5.3 Access to manufacturing facilities and surveillance
Pride’s representatives shall have reasonable access to the manufacturing facilities at all times while drilling
tubular specified on the purchase order contract is being manufactured, tested and inspected. The required
tests, 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 Zone
1 Chemistry API Spec 5DP requirements API Spec 5DP requirements
Test Frequency: One per heat Test Frequency: One per heat per lot
per lot
2 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 welds
4 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.





5” OD, 19.50 ppf, S135, API NC50
(6⅝” OD x 2¾” ID)

01 Mar 2011 0 2

Tests Drill Pipe Tube Body Tool Joint Weld Zone
5 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 test
6 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 a
corresponding minimum individual test value of 22 ft-lbs (30 J), out of a total of 3 Charpy V-notch specimens
tested at the 14 ºF, +/-5 ºF (or -10ºC, +/-2.8 ºC). Test specimens referenced herein are full size
10 mm x 10mm unless otherwise specified.
Note 2: Tensile yield strength across weld zone shall be at least 10% higher than pipe body tensile yield
strength; i.e.,(σy-weld x Aw) ≥ 110% x (σy-tube x Atube). Validation of tensile yield strength design by calculation
shall 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 Pipe
1. Pipe body or Round Stock
a. Visual Required
b. EMI (for W.T.≤0.350”) Applicable
c. FLUT (Internal Flaw & Thickness) Required
d. Straightness Required
e. Dimensional Data (OD, OD tolerance) Required
2. Pipe ends & upsets
a. Visual Required
b. WMPI End Area Required
c. Ovality Required
d. Internal Upset Transition length, Miu Required
e. Concentricity Required
3. Rotary Shoulder Connections (Toll Joints)
a. Visual Required
b. WMPI Required


EXAMPLE OF WORD FORM WITH EXPANDING FIELDS



Department: xxxxxxxxxxxxx

Procedure.: Management of Change Form

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:




Department: xxxxxxxxxxxxx

Procedure.: Management of Change Form

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:




Rig Performance Manager – Change Approver: Date Approved:


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

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

EXAMPLE OF PROCEDURE INCORPORATING SCREEN SHOTS

Manual Title: Quality Management Manual

Manual No.: Pride-01-08-AME


Procedure.: Tech xx Lube Sample Print & Ship Instr.

1.0 SAMPLE LUBRICANT PRINT LABEL INSTRUCTIONS

The first day of each month, or as soon as possible thereafter, the rig technical coordinator (TC) shall access
the Pride Oil Analysis webpage to print identifying labels for the lubricant and subsea samples that are
required. Note: Print one set of labels for the bottles, and one set to go on the outside of the second plastic
bag in which the filled sample will be placed.
The labels should be verified by referring to the preventive maintenance requirement that is linked to the
Sampling 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.






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.






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.


EXAMPLE OF SCIENTIFIC REPORT FOR THE DEPARTMENT OF ENERGY
Spr Expansion Conceptual Design Report
Chacahoula Site, LA

3.0 GEOLOGY OF CHACAHOULA SALT DOME

3.1 REGIONAL GEOLOGY

Salt domes within the Gulf Coast occur in two regions: a northern belt through northern
Louisiana and Mississippi and a southern belt along the Gulf Coast and offshore. The
Chacahoula salt dome is located within the Coastal Salt Dome Province of Louisiana. In this
area, active sedimentation and subsidence has been occurring since the Mesozoic Era, resulting
in 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 cycles
of 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 continues
under the accumulated weight of the sediment overburden.

The first movement of the Louann Salt probably occurred in either the late-Jurassic or the
Cretaceous. As the basin subsided, salt movement was probably initiated when the salt was
buried under a sufficiently large amount of sediment. Once salt movement commenced, the salt
would tend to form diapiric structures, such as salt ridges and salt domes where salt was buried
under a sufficiently large amount of sediment. Except around salt domes, regional faulting in the
Gulf 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 may
increase 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 upper
sections 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 are
principally composed of sands and shales. The dome is situated just north of the east-west
Miocene age geosynclinial axis and slightly west of the arcuate noth-south trending Mississippi
structural trough.

A series of normal gravity faults, trending slightly northeastward, control the region’s
subsurface structure. This faulting, attributed to progressive subsidence of the depositional
basin, is roughly parallel to the Gulf Coast geosynclinial axis and is downthrown to the south.

Task 11 - Chacahoula Draft Report_Cris.doc 10

Spr Expansion Conceptual Design Report
Chacahoula Site, LA

3.2 TOP OF SALT

Because it lies relatively close to the surface, the Chacahoula salt mass is classified as a
shallow dome. Lying within the Texas-Louisiana salt dome belt, it is elliptically shaped
structure with a rather flat top and steep sides. The location and top of salt maps are shown in
Figures 3-1 and 3-2, respectively. Near the top of salt, at an elevation of -3,000’, the east-west
axis is about three miles long; while, at a depth of about -15,000’, the long east-west axis jumps
to about 4.2 miles. The shallowest known salt occurrence was encountered near the center of
Section 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’ contour
appears to contain a little over 3 square miles. Quality of salt mass is largely unknown at this
time. 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 Map

Task 11 - Chacahoula Draft Report_Cris.doc 11

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: 04/17/07

1. System Overview

© 2007 - QUICK CONNECTORS INCORPORATED


2. 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.



3. 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.


EXAMPLE OF HS&E POLICY PROCEDURE
PB ESS, INC. Health Safety & Environmental Manual
Title: Section SP 6.02
Revision 02.1

Abrasive Wheels Page Page 1 of 4
Effective Date 02/16/07
Supersedes 11/01/02

1.0 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

PB ESS, INC. Health Safety & Environmental Manual
Title: Section SP 6.02
Revision 02.1

Abrasive 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

Technical Writing Examples

Recommended

Recommended

More Related Content

What's hot

What's hot (8)

Viewers also liked

Viewers also liked (20)

Similar to Technical Writing Examples

Similar to Technical Writing Examples (20)

Recently uploaded

Recently uploaded (20)

Technical Writing Examples