Attached files
file | filename |
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10-Q - 10-Q - HYPERDYNAMICS CORP | a16-23818_110q.htm |
EX-32.2 - EX-32.2 - HYPERDYNAMICS CORP | a16-23818_1ex32d2.htm |
EX-32.1 - EX-32.1 - HYPERDYNAMICS CORP | a16-23818_1ex32d1.htm |
EX-31.2 - EX-31.2 - HYPERDYNAMICS CORP | a16-23818_1ex31d2.htm |
EX-31.1 - EX-31.1 - HYPERDYNAMICS CORP | a16-23818_1ex31d1.htm |
EX-10.6 - EX-10.6 - HYPERDYNAMICS CORP | a16-23818_1ex10d6.htm |
EX-10.5 - EX-10.5 - HYPERDYNAMICS CORP | a16-23818_1ex10d5.htm |
EX-10.4 - EX-10.4 - HYPERDYNAMICS CORP | a16-23818_1ex10d4.htm |
EX-10.3 - EX-10.3 - HYPERDYNAMICS CORP | a16-23818_1ex10d3.htm |
EX-10.2 - EX-10.2 - HYPERDYNAMICS CORP | a16-23818_1ex10d2.htm |
EX-3.1 - EX-3.1 - HYPERDYNAMICS CORP | a16-23818_1ex3d1.htm |
Exhibit 10.1
OFFSHORE DRILLING CONTRACT No. PBA 3
BETWEEN
SCS Corporation Limited, a wholly owned subsidiary of Hyperdynamics Corporation
AND
PACIFIC DRILLING OPERATIONS LIMITED
Utilizing the Pacific Bora
Effective Date: 28 November, 2016
OFFSHORE DRILLING CONTRACT No. PBA 3
TABLE OF CONTENTS
SECTION |
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PAGE |
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RECITALS |
1 | |
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AGREEMENT |
1 | |
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1. |
DEFINITIONS, INTERPRETATION, AND EXHIBITS |
1 |
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2. |
PERFORMANCE OF THE SERVICES |
7 |
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3. |
TERM OF THE CONTRACT; TERMINATION AND SUSPENSION PROVISIONS |
10 |
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4. |
REPRESENTATIONS AND WARRANTIES |
13 |
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5. |
SAFETY |
14 |
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6. |
SECURITY |
15 |
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7. |
CONTRACTORS PERSONNEL AND EQUIPMENT |
16 |
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8. |
ITEMS TO BE FURNISHED BY COMPANY |
19 |
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9. |
COMPENSATION |
20 |
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10. |
REIMBURSEMENTS TO CONTRACTOR |
24 |
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11. |
FINANCIAL MATTERS |
25 |
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12. |
ADDITIONAL OBLIGATIONS |
27 |
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13. |
RECORDS AND INSPECTION |
29 |
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14. |
TAXES |
29 |
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15. |
IMPORT/EXPORT OBLIGATIONS |
30 |
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16. |
CLAIMS, LIABILITIES AND INDEMNITIES |
32 |
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17. |
INSURANCE |
37 |
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18. |
OWNERSHIP OF INTELLECTUAL PROPERTY |
37 |
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19. |
BUSINESS RELATIONSHIP |
38 |
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20. |
ASSIGNMENT |
38 |
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21. |
FORCE MAJEURE |
39 |
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22. |
GOVERNING LAW AND RESOLUTION OF DISPUTES |
40 |
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23. |
NOTICES, REPRESENTATIVES AND CONTACT INFORMATION |
41 |
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24. |
THIRD PARTY RIGHTS |
42 |
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25. |
GENERAL PROVISIONS |
42 |
EXHIBITS
EXHIBIT A SCOPE OF WORK
Attachment A1 Drilling Unit and Ancillary Equipment Specifications
Attachment A2 Equipment, Supplies, Material and Services to be Furnished by Company and Contractor
Attachment A3 Personnel to be Furnished by Contractor
Attachment A4 Drilling Unit Inspection and Acceptance Requirements
Attachment A5 Contractor Safety Management System
EXHIBIT B DRUG AND ALCOHOL POLICY
EXHIBIT C INSURANCE
EXHIBIT D COMPENSATION
EXHIBIT E CHANGE OF LOCALE (NOT USED)
EXHIBIT F PARENT COMPANY GUARANTEE
DRILLING CONTRACT No. PBA 3
This OFFSHORE DRILLING CONTRACT (Contract) dated as of 28 November 2016 (the Effective Date) is made by and between SCS Corporation Limited (Company), a wholly owned subsidiary of Hyperdynamics Corporation, a Delaware corporation, with offices at 12012 Wickchester Lane, Houston, Texas 77079 and Pacific Drilling Operations Limited, a British Virgin Islands Company, with representative offices at 11700 Katy Freeway, Suite 175, Houston, Texas 77079 (Contractor).
RECITALS
WHEREAS Company desires and has the legal rights to carry out drilling operations in the Area of Operations;
WHEREAS Contractor is a drilling contractor capable of carrying out the Services in the manner and the locations specified in this Contract; and
WHEREAS, Company desires to engage Contractor to perform the Services.
NOW THEREFORE in consideration of the mutual promises set out in this Contract, and other good and valuable consideration, the receipt and sufficiency of which is acknowledged, Company and Contractor agree as follows:
AGREEMENT
1. DEFINITIONS, INTERPRETATION, AND EXHIBITS
1.1 Definitions. As used in this Contract, the following capitalized terms shall have the meanings ascribed to them in this Section 1.1. Any capitalized terms used in this Contract, but not defined in this Section 1.1 shall have the meanings ascribed to them herein:
Affiliate means any legal entity which controls, is controlled by, or is under common control with, another legal entity. An entity is deemed to control another if it owns directly or indirectly at least fifty percent (50%) of either of the following:
(A) The shares entitled to vote at a general election of directors of such other entity.
(B) The voting interest in such other entity if such entity does not have either shares or directors.
Applicable Laws means laws, regulations, statutes, codes, rules, orders, permits, policies, licenses, certifications, decrees, standards or interpretations imposed by any governmental authority that apply to this Contract, including those applying within the Area of Operations or the Country where the Services are performed.
Area of Operations means the area described in Exhibit A Scope of Work, a diagram of which is included in Exhibit A Scope of Work, and any other area within Companys operational control where Contractor agrees to perform the Services.
BOP means blow out preventer.
BOP Stack means wellhead connector, BOP, LMRP, pods and subsea flex joint.
Claim means any claim, liability, loss, demand, damages, Lien, cause of action of any kind, order, subpoena, obligation, cost, royalty, fee, assessment, duty, charge, penalty, fine, judgment, interest and award (including recoverable legal counsel fees and costs of litigation of the Person asserting the Claim).
Commencement Date means the date on which all of the following requirements have been satisfied:
(A) All inspections specified in Attachment A4 to Exhibit A Scope of Work performed in accordance with Section 7.2(B) of this Contract have been completed.
(B) Contractor has obtained all necessary customs clearances, permits and licenses that Contractor must have in order to conduct the Services, except as referenced in Exhibit A Scope of Work.
(E) The Drilling Unit is ready to commence Services as specified in Exhibit A Scope of Work.
Company means the Person defined as Company in the introductory paragraph of this Contract.
Company Background Technology means technical information and know-how, including any invention, improvement or discovery, whether or not patentable, that is conceived, owned or controlled by Company prior to the Effective Date or that is generated or created by Company independently of this Contract during or after the Term of this Contract, including any patent rights which claim such technical information, know-how, or both.
Company Contract Information means all information (including business, technical, Company Background Technology, and other information) that is provided to Contractor by Company for the purposes of performing Services under this Contract, but does not include information that is any of the following:
(A) Contractor Background Technology.
(B) Available generally to the public through no act or omission of Contractor Group.
(C) Independently made available to Contractor by a third party with a legal right to disclose that information without restriction.
Company Group means Company, Companys Affiliates, Companys Contractors and Subcontractors of any tier, Joint Interest Owners and their Affiliates, and the directors, officers, employees, agents, assigns, representatives, consultants and insurers of all of them, and any other Person (excluding Contractor Group) whose presence in the Area of Operations is by invitation of any member of Company Group.
Company Items has the meaning set forth in Section 8.1.
Company Operations Base means the location, if one is listed in Exhibit A Scope of Work, from which Company stages its operations for the drilling program being conducted under this Contract.
Company Representative means the person identified as the Company Representative, as set out in the Exhibit A Scope of Work, or any other person replacing that individual as Company Representative in accordance with Section 23.2(B).
Contract means this Contract as defined in the introductory paragraph of this Contract.
Contractor means the Person defined as Contractor in the introductory paragraph of this Contract.
Contractor Background Technology means technical information and know-how, including any invention, improvement or discovery, whether or not patentable, that is conceived, owned or controlled by Contractor prior to the Effective Date or that is generated or created by Contractor independently of this Contract during or after the Term of this Contract, including any patent rights which claim such technical information, know-how, or both.
Contractor Contract Information means all information (including business, technical, Contractor Background Technology, and other information) that is provided to Company by Contractor for the purposes of this Contract, but does not include information that is any of the following:
(A) Company Background Technology.
(B) Available generally to the public through no act or omission of Company Group.
(C) Independently made available to Company by a third party with a legal right to disclose that information without restriction.
Contractor Group means (individually and collectively) Contractor, its and their Affiliated Companies, partners, parent companies, subsidiaries, interrelated companies, joint venturers, and contractors and subcontractors of any tier (other than Company and its contractors and subcontractors), and the respective directors, officers, employees, agents, assigns, representatives, managers, consultants, invitees and insurers of all of the foregoing, and any and all vessels owned, chartered, managed, or operated by Contractor, including the Drilling Unit.
Contractor Representative means the person identified as Contractor Representative, as set out in the Exhibit A Scope of Work to this Contract, or any other person replacing that individual as Contractor Representative in accordance with Section 23.2(B).
Country has the meaning set forth in Exhibit A Scope of Work.
Currency has the meaning set forth in Exhibit D Compensation.
Defense Costs includes attorneys fees, court costs, expert fees and mediation and arbitration expenses.
Dispute means any dispute or controversy (including non-contractual claims) arising directly or indirectly out of the performance of the Services of the Contract, including a Claim under this Contract and any dispute or controversy regarding this Contract.
Downhole Equipment means Drill String components, including drill pipe, bottom hole assembly components, fishing tools, specialty tools and drill stem testing tools.
DP means dynamic positioning.
Drill String has the meaning set forth in Section 7.2(E).
Drilling Unit means the drilling rig and its ancillary equipment used for the Services, as described in Attachment A1 to Exhibit A Scope of Work.
Effective Date means the date defined as Effective Date in the introductory paragraph of this Contract.
Government Official means any officer or employee of any government (including federal, state, local municipal and national governments, and any governmental department, agency, company or other instrumentality) or Public International Organization, or any political party official or any candidate for political office.
Improper Benefit has the meaning set forth in Section 12.3.
Initial Term has the meaning set forth in Section 3.1.
Joint Interest Owner means a Person (including a co-interest owner, joint venturer, partner or co-lessee of Company) who shares an economic interest in common with Company or an Affiliate of Company in relation to the Area of Operations.
Lien means charge, encumbrance or similar right available to creditors at law to secure debts owed to them.
LMRP means lower marine riser package.
Mobilization Delivery Point for the Drilling Unit means the location specified in Exhibit A Scope of Work.
Party means Company or Contractor and Parties mean both of them.
Payroll Burden has the meaning given in Exhibit D Compensation.
Person means an individual, corporation, company, association, partnership, state, statutory corporation, government entity or any other legal entity.
Personnel Home Base means the location from which Contractor normally mobilizes its personnel at the commencement of their work rotation, and may vary from individual to individual.
Personnel Rates means the day rates for Contractors personnel as specified in Attachment A3 to Exhibit A Scope of Work.
Personnel Staging Location, if one is specified in Exhibit A Scope of Work, means the point from which Contractors personnel will be transported to the well location where the Services are to be provided. The Personnel Staging Location may be designated as one location for expatriate, other approved Contractor personnel and Subcontractors, and another location for the remainder of Contractors workforce.
Point of Demobilization for the Drilling Unit means the location specified in Exhibit A Scope of Work.
Point of Origin for the Drilling Unit means the location specified in Exhibit A Scope of Work.
Pollution means a continuous or intermittent seepage, release, spill, leak, dumping or discharge of whatever nature or kind of gaseous, semi-solid, solid or liquid materials.
Port of Entry if one is specified in Exhibit A Scope of Work, means the point where Contractors Drilling Unit and other equipment will clear customs upon entry into the Country.
Property of a Person means property owned, leased or furnished by that Person or in which that Person has an economic interest.
Public International Organization means an international organization formed by states, governments, or other public international organizations, whatever the form of organization and scope of competence.
Records means information in any recorded form such as contracts, financial accounts, purchase orders, invoices, tax receipts, manifests, personnel records, timesheets, payroll records, inspection records maintained in connection with this Contract.
Service Rates means the compensation to be paid Contractor for the Services and activities described in Section 9 and Exhibit D Compensation.
Services means rig modifications, operational procedures and drilling / well control procedures for offshore drilling, as well as suspending, abandoning, sidetracking (which includes the drilling of multilateral wells), logging, testing, completion, deepening, installing Subsea Equipment or completions, fishing, piling and workovers and other work to be performed by Contractor under this Contract. The Services are further described in Exhibit A Scope of Work and the various Attachments thereto.
Subcontractor means any Person who is engaged by Contractor or by Company to provide the Services (other than a Person engaged as an employee).
Subsea Equipment means only the riser (excluding the riser tensioner system), slip joint, subsea flex joint, flexible and hydraulic hoses, subsea guidelines, choke and kill lines, LMRP and pods, BOP, BOP Stack, the wellhead connector, guidance funnels, guide lineless re-entry assembly and associated equipment, sensors and lines while below the rotary table. Subsea Equipment specifically excludes DP equipment.
Surface Equipment means all of Contractors equipment that is not defined as Subsea Equipment, regardless of whether such Surface Equipment is above or below the surface
of the water, such as DP equipment. Surface Equipment includes Downhole Equipment while it is not in the hole, i.e. above the rotary table, but does not include Downhole Equipment while it is in the hole, i.e. below the rotary table.
Term has the meaning set forth in Section 3.1.
Transaction Taxes means any value added tax, goods and services tax, sales tax, excise tax or other similar taxes.
Well Event means a blowout of a well or other uncontrolled well related incident that arises out of this Contract.
Well Event Control Costs means all of the following:
(A) The cost of regaining or attempting to regain control of a well following a Well Event affecting that well, including drilling of wells used for pressure relief to regain control and extinguishing or attempting to extinguish fires resulting from that Well Event.
(B) The cost of restoring, re-drilling or plugging and abandoning a well where restoration, re-drilling or plugging and abandoning is necessary because of a Well Event.
(C) Loss of oil or gas resulting from a Well Event.
(D) Damage to the hole, the formation, strata or reservoir resulting from a Well Event.
(E) Claims for control, cleanup, removal, assessments, damage to natural resources, and Third Party (as defined in Section 16) property damage from Pollution resulting from a Well Event.
1.2 Exhibits.
(A) All of the Exhibits and the attachments that are attached to the body of this Contract are an integral part of this Contract and are incorporated by reference into this Contract, including:
(1) Exhibit A Scope of Work and its Attachments.
(2) Exhibit B Weapons, Drug and Alcohol Policy.
(3) Exhibit C Insurance.
(4) Exhibit D Compensation.
(5) Exhibit E Change of Locale (NOT USED).
(6) Exhibit F Parent Company Guarantee.
(B) If a conflict exists between the body of this Contract and the Exhibits attached hereto, the language in the body of this Contract prevails to the extent of the conflict.
(C) If a conflict exists between the Exhibits or within an Exhibit as they apply to Contractor, the explicit provision that imposes the more onerous obligation on Contractor prevails to the extent of the conflict.
2. PERFORMANCE OF THE SERVICES
2.1 Operational Performance. Upon arrival of the Drilling Unit at the well location, Contractor shall promptly commence performing the Services.
2.2 Designation of the Well Locations; Access to Well Locations.
(A) Designation of the Well Locations. The Area of Operations or the locations of wells will be designated in Exhibit A Scope of Work. Company shall select, survey, mark, and provide coordinates of the well locations in accordance with Contractors requirements and shall provide Contractor with information for each proposed well location as per the provisions of Section 2.2(B). Contractor has the right to review such information and request additional information and data until the Contractor is fully satisfied that all required information has been provided.
(B) Access to Well Locations.
(1) Company shall provide Contractor with suitable access to and egress from the well locations. Company shall survey, or have surveyed by a third party, each well location with digital global positioning system or other appropriate means, along with bathymetric data needed by Contractor to perform drift in operations.
(2) Company shall obtain permissions necessary to enter the Area of Operations to operate at the drilling location selected by Company.
(3) Company shall provide detailed and accurate information relative to sea bottom conditions, at the drilling location including information from marine well site surveys contracted by Company for the drilling location.
(4) Company shall provide the Drilling Unit with well locations free of obstacles and obstructions and provide a conductor pipe program adequate to prevent soil and subsoil washout.
2.3 Mobilization and Drilling Unit Movements. Contractor shall direct the mobilization and movement of the Drilling Unit, including positioning the Drilling Unit at each drilling location.
2.4 Running and Cementing of Casing. Contractor shall assist Companys other contractors to run and cement casing of the sizes and at the approximate depths as directed by Company or run and cement the casing strings itself, at Companys cost. Contractor will keep thread protectors on the casing until it is removed from the racks to
be run into the hole and apply a suitable pipe thread lubricant as the casing string is made up. Contractor will preserve all protectors, and after the well is completed, reinstall the protectors on any casing remaining on location. After cement has set, the casing and cement job shall be pressure-tested in a manner and with results satisfactory to Company. If the results of this test are not satisfactory to Company, Contractor shall perform Services as suggested and overseen by Company to remedy the cause of the unsatisfactory results and shall continue its efforts until results satisfactory to Company are achieved.
2.5 Fluids Program. Contractor shall assist Companys other contractors to make, maintain and use drilling mud or completion fluids with appropriate properties for the well, including weight loss, viscosity and other general characteristics in accordance with such fluids program as Company may designate, subject only to safety considerations pursuant to Section 5, and at Companys cost. If Company requests, Contractor shall test drilling or completion fluids at least twice each tour for weight loss, viscosity and other general characteristics. Contractor shall record the results of such tests and use of fluids and additive materials in its daily drilling reports.
2.6 Formation and Sampling. Contractor shall assist Companys other contractors to keep accurate measurements and records of all formations encountered. If Company requests, Contractor shall provide support to collect and save all cores and cuttings taken according to Companys instructions and place them in labeled, separate containers to be furnished by Company, if required by Company. Cuttings and cores shall be made available to Company at the location and kept in proper storage until Company takes final possession of them.
2.7 Additional Well Services Required of Contractor. Contractor shall, while drilling the wells, measure deviation from the vertical if requested by Company, measure the depth of the hole, and if necessary in the opinion of Company, plug back or sidetrack. Contractor shall at any time prior to completion or abandonment of a well, perform any and all tests, measurements and other well services requested by Company as set forth in Exhibit A Scope of Work.
2.8 Completion, Re-completion or Working Over of Wells. Company may at any time elect to have a well completed, re-completed, worked-over or suspended. Upon notice of such election, Contractor shall perform the work of completing, re-completing or working over the well in accordance with the program provided by Company in a manner and to the extent desired by Company.
2.9 Stoppage of the Services for Convenience. Company may elect to stop the Services at any time for convenience without any default by Contractor in performance of the Services. Contractor shall be paid at the Operating Rate during any stoppage period.
2.10 Abandonment of Wells. Company may at any time elect to have a well abandoned at any depth. Upon notice of such election, Contractor shall abandon the hole in accordance with the program provided by Company, in a manner satisfactory to Company and in compliance with all Applicable Laws with respect to well abandonment.
2.11 Loss of Control of the Hole.
(A) Subject to the provisions of this Section 2.11, if abnormal drilling conditions that may result in a loss of control of the hole occur during performance of the
Services, Contractor shall endeavor to correct and control any such abnormal drilling condition.
(B) Subject to Sections 9.1(G) and 16.5, if the hole is lost or damaged, Contractor shall, at Companys election, drill a relief well, a new hole on the same location or re-drill sections of the existing hole as Company may require. These activities shall be subject to Contractors underwriters approval and if an increase or additional premium is required for such activities, Company shall pay that increase or additional premium in the event a relief well is required.
2.12 Removal of Wreckage. If the Drilling Unit or any part thereof is lost or damaged beyond repair and removal is required by law or governmental authority, or the wreckage is interfering with Companys operations, Contractor shall promptly remove the damaged or lost Drilling Unit or part thereof from the Area of Operations. Company shall reimburse Contractor for any amounts in excess of [One Million Dollars (US $1,000,000)] in connection with such removal. If removal is not required by law or recommended by government agency, Company shall remove the wreckage or portions of it that Company wants removed, at Companys sole cost and expense.
2.13 Well Records and Reports.
(A) Contractor shall maintain a history and log of Services performed. The history and log must be open at all times to inspection by Company and copies furnished to Companys authorized employees and representatives upon their request.
(B) Contractor shall furnish Companys Representative with a daily written report, showing depths and Services performed during the preceding twenty-four (24) hours and any other information relative to the days Services requested by Company.
2.14 Change of Area of Operations or Country.
(A) Company may request to change the locale of the Services requiring a change in the Area of Operations or the Country if all of the following circumstances exist:
(1) The change will not result in a breach of Contractors trading representations or warranties made to its insurance underwriters and will not violate any Applicable Laws or other laws and regulations applicable to Contractor or its Affiliates.
(2) The change will not necessitate a material change in operating structure.
(3) Contractor will be able to obtain all insurance required by the Contract, and any other insurance typically carried by Contractor, for Services in the new Area of Operations or Country.
(B) In conjunction with a request from Company for a change of locale for the Services, Company and Contractor will review the Scope of Work and its Attachments to determine if amendments are needed as a result of any of the following:
(1) Material changes in financial impact arising from the requested change in locale, which includes the financial impact on Contractor with respect to differences in taxes, labor rates, operating costs, shore base office costs, Contractors corporate operating structure, agency fees, etc.
(2) A change in the Point of Demobilization for the Drilling Unit.
(3) Material changes in the terms of the Scope of Work and its Attachments appropriate for the new locale.
(4) Any changes to the Scope of Work and its Attachments for the purposes of this Section 2.14 will be structured such that Contractors financial situation should not be adversely affected nor advantaged by the change of locale.
(C) Any mutually agreed changes will be specified in a written amendment to this Contract, signed by the Parties in accordance with Section 25.2, prior to mobilization of the Drilling Unit to the new locale. This amendment must include new Service Rates, new lump sum reimbursements (if any) and reset any Baseline Operating Costs (as defined in Exhibit D Compensation) for rate adjustments to reflect the new locale.
2.15 Loading/Unloading of materials to/from the Drilling Unit. Upon Companys request, Contractors personnel shall supervise the loading and the unloading of materials to and from the Drilling Unit in the Area of Operations; provided, however, Contractors personnel shall not be required to board supply vessels for loading or unloading materials.
2.16 Station Keeping for Dynamic Positioning. If the Drilling Unit is equipped with DP equipment for station keeping, Contractor shall safely conduct its Services in the governing metocean conditions and presence of facilities, other vessels or floating or suspended articles. Contractor shall monitor the riser profile and flex joint differential angles to reasonably avoid key seating of flex joints or riser joints.
3. TERM OF THE CONTRACT; TERMINATION AND SUSPENSION PROVISIONS
3.1 Term of the Contract. This Contract will remain in full force and effect from the Commencement Effective Date through the initial term of the Contract (the Initial Term) or any extension thereof (the Term) unless terminated earlier by either Company or Contractor as set forth in this Section 3. Notwithstanding the definition of Effective Date, the Commencement Date is deemed to occur when Contractor has satisfied all its obligations referenced in the Commencement Date definition, except those obligations Contractor has been unable to complete through failure of Company to perform its obligations in a timely manner.
3.2 Initial Term of the Contract.
(A) The Initial Term of this Contract starts on the Commencement Date and extends for (i) the length of time or (ii) the number of wells stipulated in Exhibit A Scope of Work until the date that Contractor completes either of the following:
(1) The completion or abandonment of the number of wells provided in Exhibit A Scope of Work; or
(2) Not used
(B) Companys Option to Extend the Initial Term of the Contract. Company may extend the Initial Term of this Contract at the same rates set forth in Exhibit D Compensation as follows:
(1) Company shall have the right to exercise the first option well (Option Well) not later than 5 days after the first well (Firm Well) has been spudded. Should the Option Well be declared, Company shall have the right to exercise up to two (2) more wells (Additional Wells) no later than completion of the Firm Well.
(2) NOT USED
(3) NOT USED
(4) NOT USED
(C) Further Extensions of the Term of the Contract. In case such extension falls within the calendar year of 2017, the same rates as set forth in Exhibit D Compensation. Should any extensions fall beyond 2017, the rates as set forth in Exhibit D may be renegotiated and mutually agreed.
3.3 Termination of the Contract by Company without an Opportunity to Cure. This Contract may be terminated by Company without penalty to Company as follows:
(A) If Contractor or its parent company should become insolvent or make an assignment for the benefit of creditors or file a voluntary petition for bankruptcy or if involuntary bankruptcy or receivership proceedings should be instituted against Contractor or its parent company and such relief action, voluntary or involuntary petition or receivership proceeding is not stayed or withdrawn within one hundred and twenty (120) days;
(B) Upon Companys providing Contractor with fifteen (15) days written notice after the number of days specified in Exhibit A Scope of Work following the occurrence and subsistence of a Force Majeure Event.
(C) If the Drilling Unit becomes an actual or constructive total loss and Contractor is unable to supply Company with a substitute vessel within a period of thirty (30) days.
(D) Company shall waive its right to terminate for any single occurrence under the conditions set forth after a period of seven (7) days from cure.
3.4 Termination of the Contract by Company with an Opportunity to Cure.
(A) Company may terminate the Contract if Contractor fails to initiate reasonable corrective action within seventy-two (72) hours after written notice from
Company, or fails to complete corrective action to Companys satisfaction within twenty-five (25) days after such notice, or within another time frame reasonably determined by Company, should Contractor:
(1) Materially default in the performance of the Services after the Effective Date of the Contract.
(2) Subject to Section 12.3, fail to obtain approval for, or maintain in effect, permits, certifications or clearances required to be in Contractors name or to be secured by Contractor from the appropriate governmental regulatory bodies of the Country or any political subdivision thereof or certification authorities which are necessary to conduct Services in the Area of Operations.
(3) Fail to maintain insurance as required by Section 17.
3.5 Termination of the Contract by Company for Convenience. Company may terminate this Contract for convenience by giving Contractor thirty (30) days prior written notice of termination.
3.6 NOT USED
3.7 Payments and Actions by Company upon Termination of the Contract.
(A) If Company terminates this Contract pursuant to Sections 3.3 or Contractor terminates this Contract pursuant to Section 3.6, Company shall pay Contractor for that portion of the Services, including mobilization and demobilization as appropriate, that Contractor performed prior to the date of such termination. In addition, Company shall pay Contractor an amount reasonably calculated to compensate Contractor for documented expenses it has incurred for the purpose of performing its operational obligations under this Contract.
(B) If this Contract is terminated pursuant to Section 3.3(B), Company shall pay Contractor all sums outlined in Section 3.7(A) If this Contract is terminated pursuant to Section 3.5, Company shall pay Contractor all sums outlined in Section 3.7(A), and one hundred percent (100%) of the Operating Rate in monthly installments for the remainder of the Term of the Contract (remainder of the Term shall mean the remainder of the approved AFE days in the current Term, including any extensions) or any extension thereof effective from the date of termination. If, after termination, Contractor obtains replacement work within what would have been the remainder of the Term or extension of this Contract, then Companys obligation to pay the referenced termination fees, specified in Section 3.7(B) above, will be decreased by the day rate paid to Contractor by the new operator though the remainder of the Term of the Contract as referenced above. Company shall not share in any rates that exceed the applicable rates.
3.8 Suspension of Services under the Contract for Cause.
(A) Right to Suspend. Company may, by providing notice to Contractor, suspend with immediate effect this Contract for a maximum of twenty-one (21) days pursuant to Sections 9.2(1)(a) and 9.2(2)(a).
(B) Compensation and Expenses during Suspension. If Company suspends the Services under this Contract pursuant to this Section 3.8(A), Contractor shall not be entitled to compensation during such period of suspension (which shall not exceed twenty-one (21) days) except for reimbursement of expenses incurred by Contractor.
4. REPRESENTATIONS AND WARRANTIES
4.1 Contractors Representations. Contractor represents and warrants to Company that as of the Effective Date:
(A) Contractor is a corporation or company (as the case may be) duly organized, validly existing and in good standing under the laws or the jurisdiction of its organization.
(B) Contractor has full corporate or company power and authority to enter into and perform this Contract, and has taken all actions necessary to authorize its execution and delivery of this Contract.
(C) This Contract has been duly executed and delivered by its authorized officer or other representative and constitutes its legal, valid and binding obligation enforceable in accordance with its terms, and no consent or approval of any other Person is required in connection with its execution, delivery and performance of this Contract.
(D) No event has occurred prior to the Effective Date which, had it occurred after the Effective Date, would constitute a violation of Section 12.2.
(E) The execution, delivery and performance of this Contract by Contractor, and the consummation of the transactions contemplated by this Contract, will not violate any provision of Contractors governing documents, result in a default or the creation of any lien, give rise to any right of termination, cancellation or acceleration under any material note, bond, mortgage, indenture or agreement, violate any judgment, order, ruling or regulation applicable to Contractor or violate any law applicable to Contractor.
(F) Contractors provision of personnel, and the personnel provided, shall comply in all respects with the requirements of Section 7.1
(G) Contractors provision of the Drilling Unit, services, supplies, systems and equipment, and the Drilling Unit, services, supplies, systems and equipment provided, shall comply in all respects with the requirements of Section 7.2.
4.2 Companys Representations. Company represents and warrants to Contractor that as of the Effective Date:
(A) Company is a corporation or company (as the case may be) duly organized, validly existing and in good standing under the laws or the jurisdiction of its organization.
(B) Company has full corporate or company power and authority to enter into and perform this Contract, and has taken all actions necessary to authorize its execution and delivery of this Contract.
(C) This Contract has been duly executed and delivered by its authorized officer or other representative and constitutes its legal, valid and binding obligation enforceable in accordance with its terms, and no consent or approval of any other Person is required in connection with its execution, delivery and performance of this Contract.
(D) No event has occurred prior to the Effective Date which, had it occurred after the Effective Date, would constitute a violation of Section 12.2.
(E) The execution, delivery and performance of this Contract by Company, and the consummation of the transactions contemplated by this Contract, will not violate any provision of Companys governing documents, result in a default or the creation of any lien, give rise to any right of termination, cancellation or acceleration under any material note, bond, mortgage, indenture or agreement, violate any judgment, order, ruling or regulation applicable to Company or violate any law applicable to Company.
5. SAFETY
5.1 Notification of Hazardous Conditions and Stoppage of Services. Company and Contractor have the following rights and obligations relative to safety:
(A) Notice of Hazardous Conditions. If at any time Contractor or Company determines that Services cannot be safely undertaken or Services may create a hazardous condition, that Party shall verbally notify the other Party of such determination. As soon as reasonably possible after such determination is made, Contractor shall consult with Company prior to deciding on the subsequent course of action. At all times Contractor shall make every effort that in its opinion is required to control or overcome the cause of or minimize the adverse effect of the hazardous condition.
(B) Stop Work Authority. Both Company and Contractor have the right to stop performance of the Services by Contractor, any of its Subcontractors or any of Companys other contractors when work conditions are deemed to be imminently hazardous to Persons, Property or the environment and the requisite notice is given pursuant to Section 5.1(A).
(C) Contractors Opinion Controls. In case of conflict between Company and Contractor as to the determination of the course of conduct which affords the greatest safety, Contractors opinion shall control.
5.2 Contractors Safety Management System. Prior to the Commencement Date, Contractor shall submit to Company a copy of Contractors Safety Management System. The Safety Management System will be attached as Attachment A5 to Exhibit A Scope of Work. All policies and procedures comprising the Safety Management System shall apply to all Persons including Company Group.
5.3 Installation of Blowout Prevention Devices. As soon as Contractor considers it advisable, or earlier if requested by Company, Contractor shall install blowout prevention devices on each well as specified in Attachment A1 to Exhibit A Scope of Work.
5.4 Notification of Safety Requirements to Personnel on the Drilling Unit and Safety Training.
(A) Contractor shall give notice to Contractor Group and Company Group at the well location or in the Area of Operations of all safety requirements that apply in those areas.
(B) Contractor shall take appropriate action requiring all Persons to cease activities whenever Contractor is aware that Persons are not complying with safety requirements.
(C) Company and Contractor will consult and cooperate to get the appropriate notices and information to contractors of Company and to implement this Section 5.4 with other contractors and their personnel.
5.5 Material Safety Data Sheets. Contractor shall review material safety data sheets (MSDS) pertaining to known toxic and hazardous substances or chemical hazards to which Contractors employees or Subcontractors are likely to be exposed while performing any particular or individual work task on behalf of Company.
5.6 Emergency Evacuation Plan. Contractor shall provide Company information necessary for Company to submit an Emergency Evacuation Plan consistent with the requirements of all applicable regulations issued by the applicable regulatory body.
5.7 Waste Disposal. Contractor shall use the accepted and approved standards of care and diligence in use by international drilling contractors and as stipulated by local and other applicable legislation to prevent, take care of, and prepare for shipment all its waste oil, waste water, and other waste material, including but not limited to waste paint cans, waste drilling pipe, etc., that may accumulate from Contractors Services.
5.8 Contractors Subcontractors. The requirements of this Section 5 are applicable to all Subcontractors hired by Contractor and Contractor shall require its Subcontractors compliance with this Section 5.
6. SECURITY
6.1 Contractors Obligations. Contractor shall be solely responsible for ensuring the safety and welfare of any Person on the Drilling Unit and shall implement any measures it deems fit to protect any member of Contractor Group or Company Group all persons on the Drilling Unit and Contractor property. If in Contractors sole opinion, actual or potential risks exist, including riots and other disturbances Contractor
reserves the right to implement emergency procedures including evacuation.
6.2 Companys Obligations Company shall be solely responsible for ensuring safety and welfare of any Person including Contractor Group in the Area of Operations from acts of violence including but not limited to kidnapping and hostage taking. Company shall provide Contractor copies of its safety procedures and shall make available to Contractor its infrastructure and manpower to enable Contractor to conduct emergency procedures.
7. CONTRACTORS PERSONNEL AND EQUIPMENT
7.1 Contractors Personnel. Contractor shall provide the personnel identified in Attachment A3 to Exhibit A Scope of Work and comply with all of the following:
(A) Qualifications and Number of Personnel.
(1) The personnel assigned by or on behalf of Contractor must be qualified, competent, sufficiently experienced and in a sufficient number to perform the Services.
(2) If Company requests additional personnel, Contractor shall furnish the requested additional personnel (in addition to those required in Attachment A3 to Exhibit A Scope of Work) and Company shall reimburse Contractor for this added cost as set out in Section 10.2.
(3) Each of Contractors personnel in the following classifications must be fluent in English: Contractor Representative, drilling superintendent, senior toolpusher, toolpusher, drillers and assistant drillers, master, or their equivalent job classifications. Contractor must have at least one person who can both speak and write English on site at all times who is capable of communicating both orally and in writing with other personnel at the well location who do not understand oral or written English.
(B) Training and Certification. Contractor shall provide or cause to be provided all necessary training, education, instruction and supervision of Contractor personnel that is necessary to carry out the duties required in this Contract.
(1) Contractor warrants that all drill crew personnel specified in Attachment A3 to Exhibit A Scope of Work are properly certified in well control operations.
(2) Contractor shall ensure that Contractors personnel comply with all Applicable Laws regarding the attendance at and satisfactory completion of firefighting and survival courses.
(C) Discipline and Replacement of Personnel. Contractor shall take all measures to maintain discipline and lawful and orderly behavior among Contractor personnel during the performance of the Services. If instructed by Company in writing, Contractor shall replace or remove Contractor Group personnel as follows:
(1) Contractor shall remove and shall have a reasonable time to replace any of its personnel, if requested by Company in writing and for just cause following a consultation with Contractor, and in this event, Company shall reimburse to Contractor all costs, including travel costs incurred by such removal and replacement unless such removal has been initiated by the Company due to non-compliance with this Contract and/or violation of Applicable Laws by personnel removed.
(2) Contractor shall handle all industrial relations matters involving Contractors personnel subject to Applicable Laws, labor contracts, and customs. The settlement of any labor disturbance affecting Contractors personnel will be wholly within the discretion of Contractor.
(D) Personnel Work Schedule. Contractors personnel shall work according to the schedule as set forth in Exhibit A and attachment A3 Scope of Work.
7.2 Contractors Drilling Unit, Services and Supplies.
(A) General Provision. Contractor and Company shall provide all items as listed on Attachment 2 to Exhibit A Scope of Work, as applicable. Prior to commencing the Services, Contractor at its sole discretion shall be able to substitute the Drilling Unit upon written notice to Company.
(B) Inspection of the Drilling Unit and the Services. Company or its authorized representatives may, at Companys sole cost and expense, inspect the Drilling Unit, as well as check all records, measurements and tests prior to the Commencement Date as provided in Attachment A4 to Exhibit A Scope of Work as well as while the Contract is valid with a due notification to the Contractor. Any such inspections after the commencement date shall be at Operating Rate.
(C) Maintenance of the Drilling Unit and Ancillary Equipment.
(1) Contractor shall ensure that the Drilling Unit and all other items of Contractors equipment are properly maintained in good working order and repair throughout the term of the Contract. Except as otherwise provided in Attachment A2 to Exhibit A Scope of Work, all costs related to any repairs or replacements of the Drilling Unit will be effected by Contractor at its sole cost and expense.
(2) Contractor shall have a demonstrable Preventative Maintenance System (PMS). The repair and maintenance of all equipment located on the Drilling Unit including all Contractor equipment and Company equipment will be covered in the said PMS.
(3) Contractor will be allowed a maximum number of hours per calendar month, as set forth in Exhibit A Scope of Work, for repair and preventive maintenance of critical surface drilling items, for which payment will be made at the Operating Rate stated in Exhibit D Compensation. This allotment of time allowed for repair and
preventive maintenance of drilling items shall be cumulative from month to month and may be carried forward, rolled-over and banked to any future month. The time spent in changing mud pump fluid end components, replacement of swivel packing, slipping and cutting of drill line and other similar routine inspections and maintenance operations, which do not unreasonably impede the progress of critical path operations, shall not be applied toward the time period in the maintenance provision of this Section 7.2 or elsewhere in this Contract.
(D) Certification of the Drilling Unit.
(1) With respect to suitability of use for offshore Services, the Drilling Unit shall be classed and certified by Lloyds, the American Bureau of Shipping, or Det Norske Veritas (DNV). Contractor shall keep the Drilling Unit properly classed and certified throughout the Term of Contract, and a copy of the latest class survey, along with an estimated drydock schedule for the Drilling Unit, shall be provided to Company prior to the Commencement Date of the Contract.
(2) Contractor shall conduct, at Contractors sole cost and expense, a classification and other regulatory inspections of the Drilling Unit by qualified surveyors prior to the Commencement Date.
(3) The estimated schedule for the inspections to be carried out in accordance with this Section 7 is specified in Exhibit A Scope of Work and will be updated periodically throughout the Term of the Contract.
(E) Contractors Drill String. Contractor shall supply a new or used string of internally coated drill pipe, drill collars and subs (Drill String) and handling equipment in accordance with the requirements of Attachment A1 to Exhibit A Scope of Work.
(F) Hoisting Equipment. Contractor shall provide and maintain all hoisting equipment in accordance with industry standards and as provided in Attachment A1 to Exhibit A Scope of Work.
(G) Contractors BOP and Well Control Systems. Contractor shall provide and maintain all BOP and Subsea control systems as per Attachment A1 to Exhibit A Scope of Work and maintain such equipment in accordance with industry standards and as provided in this Section 7.2(G) and the specifications set forth in Attachment A4 to Exhibit A Scope of Work.
(1) After each drilled well Contractor shall have the right to recover, replace, reconnect, test in line and deploy BOPs at Operating Rate as defined in Exhibit D Compensation.
(2) Contractor shall provide Company written documentation for all repairs and modifications to the equipment and systems.
(H) Additional Materials. At Companys written request, and subject to Contractors agreement as referenced in Section 10.1, Contractor will provide additional materials that are not listed on Exhibit A Scope of Work and attachments or are not an integral part of the Drilling Unit. Company shall reimburse Contractor for such materials in accordance with the provisions of Section 10.1.
8. ITEMS TO BE FURNISHED BY COMPANY
8.1 Company Items.
(A) Company shall furnish, maintain and replace as necessary, at its sole cost and expense, the equipment, machinery, tools, supplies, materials, items and services specified in Attachment A2 to Exhibit A Scope of Work (Company Items). Company Items include items furnished by Contractor at Companys cost whether with or without a handling charge. Alternatively, Company may ask Contractor to furnish any of the Company Items and if Contractor accepts, Company shall reimburse Contractor as provided in Section 10.1.
(B) The Representatives of Company and Contractor will jointly take an inventory of all Company Items (i) prior to the Commencement Date, (ii) after completion or termination of each well, and (ii) at completion of the Services or, if this Contract is terminated earlier, the date of termination.
(C) Upon receipt of any Company Item, Contractor shall verify receipt and visually inspect same with reasonable diligence and shall advise Company of any shortages and defects observed. Contractor shall have no duty to advise Company of any defects not apparent by visual inspection.
(D) Company shall provide the routine maintenance required to keep Company Items in good and safe operating condition. If Company Items require repair or maintenance work beyond the scope of routine maintenance or require replacement, Company shall pay for any such repair or replacement. If Company requests Contractor to provide such maintenance, repair or replacement, Contractor shall use efforts consistent with generally accepted industry standards to conduct such maintenance, repairs or replacement and Company shall reimburse Contractor in the manner provided in Section 10.1. Contractor shall be compensated for any downtime directly associated with the Company Items at the Operating Rate as indicated in Exhibit D Compensation.
(E) Company may, upon giving reasonable notice to Contractor and subject to Contractors acceptance, instruct Contractor to furnish any of the items listed in Attachment A2 to Exhibit A Scope of Work which Company is required to furnish, and such items will at all times be considered Company Items and personnel (if applicable) unless otherwise mutually agreed in writing. If items are so furnished, Company shall reimburse Contractor pursuant to Section 10.1.
(F) All Company Items which are not consumed during the performance of Services must be returned to Company, unless the Parties agree otherwise.
(G) Subject to Section 15, Company is not entitled to any compensation from Contractor for normal wear and tear or damage or loss of Company Items or for the consumption of any Company Items used by Contractor during the performance of Services.
(H) Within three (3) months after completion of the Services or, if this Contract is terminated earlier, within three (3) months following the effective date of such termination, Contractor shall provide Company a reconciliation of all Company Items. To the extent allowed by Applicable Laws, and to the extent transferable, Company will provide Contractor with the benefits of any warranties on the Company Items that Company has received from the Company Items manufacturers or distributors.
8.2 Emergency Medical Treatment and Emergency Medical Evacuation. Company shall make available to Contractor and its Subcontractors access to emergency medical evacuation services to, and emergency medical treatment at local Conakry medical facilities (Clinique Ambrose Pare).
8.3 Transportation of Contractors Personnel and Additional Materials. Company shall provide transportation for Contractors personnel and additional materials from the Personnel Staging Location as provided in Exhibit A Scope of Work to the Area of Operations. If Company requests additional materials as per Section 7.2(H), Company shall arrange for and provide the associated transportation, either as part of a regular trip or a special trip.
8.4 NOT USED
9. COMPENSATION.
9.1 Service Rates. Contractor shall be compensated by Company for performing the Services under the Contract and the Company shall reimburse the Contractor in accordance with the rates set forth in Exhibit D Compensation and in accordance with the provisions of Sections 9.1(A) through 9.1(I) as full compensation for Services rendered and provision of the Drilling Unit, equipment, personnel, materials, machinery, Drill Strings, tools, spare parts and supplies furnished by Contractor in conformance with this Contract. Daily rates shall be prorated on the basis of a twenty-four (24) hour calendar day to the nearest one-half hour.
(A) Mobilization Fee. Contractors mobilization fee for the Drilling Unit and crew and for performing all Services, including all Services necessary to otherwise prepare for commencement of actual drilling Services at the first well location shall be as specified in Exhibit D Compensation, if one is agreed to be paid in Exhibit D Compensation. Mobilization commences from the Point of Origin for the Drilling Unit identified in Exhibit A Scope of Work and is complete when the Drilling Unit arrives at the Mobilization Delivery Point identified in Exhibit A Scope of Work with all required equipment specified in Attachment A1 of Exhibit A Scope of Work on board in full readiness to commence Services when so instructed by Company and Company has issued Acceptance of the Drilling Unit as per Attachment A4 to Exhibit A Scope of Work. Contractor shall invoice Company for the Mobilization Fee within thirty (30) days after the Commencement Date.
(B) Operating Rate. Subject to being superseded by any other rate or fee provided for in this Section 9.1, Company shall pay Contractor the Operating Rate specified in Exhibit D Compensation per twenty-four (24) hour day (subject to pro-ration) beginning on the Commencement Date and continuing during the Term of the Contract, including but not limited to, drilling, suspending or abandoning, sidetracking (which for sake of clarity includes the drilling of multilateral wells), subsea completions, workovers, or testing, deepening, reaming, coring, drill stem testing, picking up drill pipe, tripping, circulating and conditioning mud, running and cementing casing, waiting for cement, logging, performing routine maintenance, waiting for orders, nippling up, running tubing, testing, completing and re-completing the well and swabbing and slipping and cutting the drilling line.
(C) Moving Rate. The Moving Rate will be in effect during the time when the Drilling Unit is being moved between Company well locations within the Country. It starts when the Drilling Unit starts toward the next well location and continues to be paid while the Drilling Unit is in transit. The Moving Rate ceases to be paid when the Drilling Unit arrives at the next well location. Both Parties may agree to a lump sum Moving Rate charge for transporting the Drilling Unit between well locations instead of a daily rate.
(D) International Moving Rate. The International Moving Rate applies to all moves from one Country to another Country as specified in Exhibit D Compensation.
(E) Standby Rate. The Standby Rate will be in effect at any time when the Drilling Unit is on location, fully manned and operational and otherwise held in full readiness to proceed with Services, but is unable to undertake Services because of one of the following:
(1) The Drilling Unit is shut down for local holidays in accordance with Applicable Laws or, at Companys request, the drilling Services are shut down; or
(2) Waiting on instructions from Company or delivery of equipment, materials or supplies to be furnished by the Company:
(3) Failure or loss of or damage to Company Items or equipment, unless caused by sole fault of Contractor, in such case zero rate shall apply until critical path operations have resumed.
Under this Section 9.1(E), during the first twenty-four (24) consecutive hours of Standby, the Operating Rate as specified in Section 9.1(B) shall apply. After the first twenty-four (24) hours of Standby, Company shall pay Contractor the Standby Rate specified in Exhibit D Compensation per twenty-four (24) hour day (subject to pro-ration) until: (a) Services are recommenced or (b) the Contract is terminated or expires, whichever is earlier.
Company shall provide Contractor advance written notice prior to the end of a Standby period within the number of calendar days required in Exhibit A Scope of Work.
(F) Force Majeure Event Rate.
(1) If any Force Majeure Event causes the suspension of Services, then:
(a) Contractor shall be entitled to receive the Force Majeure Rate for a maximum period of twenty (20) consecutive days provided, however, if suspension of Services continues beyond twenty (20) days, Company shall thereafter pay Contractor Force Majeure Rate until recommencement of Services or the Contract is terminated as set forth in Section 9.1(F)(1)(a). Force Majeure Rate shall apply during any repairs to Contractors equipment necessitated by damage caused by a Force Majeure Event; or
(b) Company may terminate this Contract pursuant to Section 3.3(B).
(G) Redrill Rate. If all or part of the hole is lost or damaged due to Contractors sole fault and Company elects that Contractor re-drill a portion of the hole, then Company shall pay Contractor at the Redrill Rate specified in Exhibit D Compensation. If Contractor is not at fault for the loss or damage to the hole, Contractor shall be paid Operating Rate.
(H) Demobilization Fee. As full compensation for demobilizing the Drilling Unit and Contractors expatriate and national personnel on completion or abandonment of the last well to be drilled under this Contract, or upon early termination of the Contract in accordance with the provisions of Section 3.7, Company shall pay Contractor the Demobilization Fee, if one is specified in Exhibit D Compensation. The Demobilization Fee may be expressed as a lump sum, a daily Service Rate or a combination of both. Demobilization commences when the Drilling Unit is one nautical mile from the last well location.
(I) Off Weather Rate. When normal Services cannot be carried out due to adverse sea, loop/eddy currents, or adverse weather conditions, such as named tropical storms or inability to move due to weather Operating Rate (or other applicable rate) shall apply for up to twenty-four (24) consecutive hours. Thereafter, Company shall pay the Off Weather Rate specified in Exhibit D Compensation per twenty-four (24) hour day until Services are recommenced or the Contract terminates or expires, whichever is earlier. Contractors superintendent in charge aboard the Drilling Unit will make final determination as to when Services are to be suspended and resumed in the event of these conditions.
9.2 Stoppage of Services due to Mechanical Failure or Damage to the Drilling Unit. If mechanical problems associated with or any damage to the Drilling Unit prevents Contractors performance of the Services and are not directly caused by the Company Group or a Force Majeure Event, the provisions in this Section 9.2 will apply.
(1) Surface Equipment.
(a) If the stoppage of the Services is due to mechanical failure or damage to the Surface Equipment, Contractor is allowed the number of hours per calendar month to effect repairs to the Drilling Unit as set out in Exhibit A Scope of Work. After such allowance is used up, Contractor will be on the zero Service Rate and receive no further compensation from Company until either the recommencement of the Services or the Contract is terminated or expires. If a failure occurs in the surface BOP controls system and results in recovering the LMRP or BOP Stack, Section 9.2(2) applies.
(b) NOT USED
(2) Subsea Equipment.
(a) Except as otherwise provided in Section 9.2(2)(b), if the stoppage of the Services is due to a mechanical failure or damage to the Subsea Equipment, Contractor will be on zero Service Rate and receive no further compensation from Company until either the recommencement of the Services or the Contract is terminated or expires.
(b) If the BOP Stack has been deployed and functional, with or without the LMRP, in excess of ninety (90) days from when the BOP Stack is released from the transportation cart, and a stoppage of the Services occurs due to mechanical failure or damage to the BOP Stack, Contractor shall recover, replace, reconnect, test in line and deploy a BOP Stack at eighty-five percent (85%) of Operating Rate until either the recommencement of the Services or the Contract is terminated or expires. If the BOP Stack has been deployed and functional, with or without the LMRP, in excess of one hundred and twenty (120) days from when the BOP Stack is released from the transportation cart, and a stoppage of the Services occurs due to mechanical failure or damage to BOP Stack, Contractor shall recover, replace, reconnect, test in line and deploy a BOP Stack at Operating Rate until either the recommencement of the Services or the Contract is terminated or expires. If a failure occurs in the surface BOP controls system and does not result in recovering the LMRP or BOP Stack, Section 9.2(1) applies.
(c) If at Companys request the spare BOP Stack, if any, has a different configuration from the deployed BOP Stack (i.e. drilling versus completion), and Services are stopped to recover the deployed BOP Stack, any incremental time required on the critical path to reconfigure and test the spare BOP Stack for deployment shall be at Operating Rate.
9.3 Variation of Service Rates. The Service Rates set forth in Exhibit D Compensation may be revised as follows:
(A) Variation of Rates for Changes in the Area of Operations or Companys supply base. If there is a change in the Area of Operations identified in Exhibit A Scope of Work or Company Operations Base, Contractor may request an adjustment to the Service Rates relative to Contractors documented costs that result from the change. Following such request the Parties shall execute an amendment to Exhibit D Compensation.
(B) Variation of Service Rates for Changes in Companys Policies. If there is a change to Companys policies, including applicable codes and standards adopted by Company, which materially increase Contractors costs, Contractor may request an adjustment to the Service Rates that result from the change. Following such request the Parties shall execute an amendment to Exhibit D Compensation.
(C) Variation of Service Rates due to a Change in Work Schedule/Number of Personnel. If a change in Exhibit A Scope of Work increases Contractors personnel Contractor may request an increase in the Service Rates relative to Contractors documented costs which result from such change. Following such request the Parties shall execute an amendment to Exhibit D Compensation.
(i) NOT USED
(D) Catering Cost Variation. For purposes of this escalation, the baseline catering cost shown in Section II, Item 8 in Exhibit D Compensation will be adjusted for any documented actual cost variation.
(E) Variation of Rates Due to Exchange Controls. If, after the Effective Date of the Contract, the Country either imposes exchange controls through new legislation or regulations or through a change in interpretation or enforcement of existing legislation or regulations, the Parties agree to consider an adjustment in Contractors compensation to ensure that neither Party benefits nor is disadvantaged as a result thereof.
(F) Variation of Rates due to Changes in Law or Regulation. If after the Effective Date any change in law or regulation or interpretation of any law or regulation (including any tax or customs law or regulation) causes an increase in Contractors operating costs then the Parties agree to negotiate an adjustment in Contractors compensation to ensure that the Contractor is not disadvantaged as a result of that change.
10. REIMBURSEMENTS TO CONTRACTOR
10.1 Reimbursement for Additional Materials and Services. If Company elects to have Contractor furnish certain additional materials and services not included on Exhibit A Scope of Work and its attachments and Contractor agrees to furnish such materials and perform or arrange for the performance of such Services, Company shall reimburse Contractor for the actual cost including customs duties and freight costs incurred in furnishing such items. In addition, Contractor shall be entitled to charge Company a
handling charge in accordance with the following amounts or percentages of the Contractors net final cost for such service or materials:
(A) Five percent (5%) for all materials and services listed in Attachment A2 to Exhibit A Scope of Work to be provided by Contractor at Companys cost plus a handling fee;
(B) Five percent (5%) for all materials and services requested after Contract signing but before the shipyards vessel launching milestone;
(C) Five percent 5(%) for all materials and services requested after the shipyards vessel launching milestone but before shipyards delivery of the Drilling Unit;
(D) Five percent (5%) for all materials and services requested after the shipyards delivery of the Drilling Unit but before the Commencement Date; and
(E) Five percent (5%) for all materials and services requested after the Commencement Date.
10.2 Reimbursement for Additional Personnel. Contractor shall be reimbursed for additional personnel requested by Company at the rates listed on Attachment A3 to Exhibit A Scope of Work. In the absence of such listed personnel rates for the required positions, Company shall reimburse Contractor for the cost of additional personnel, as provided in Section 7.1(A)(2), on the basis of one of the following:
(A) A lump sum amount that is agreed to by the Parties. The Parties agree to incorporate this amount into the applicable daily rates by entering into an amendment of Exhibit D Compensation.
(B) An amount equal to Contractors cost for salary plus Payroll Burden (as defined in Exhibit D Compensation) plus five percent (5%) of such amount.
10.3 Reimbursement for Contractors Personnel Air Transportation. At any time Company is required to reimburse Contractor for personnel air transportation, Company shall reimburse Contractor the cost of air transportation up to but not to exceed the cost of the applicable air fare, according to Contractors travel policy, by the most expedient route to and from each Persons Personnel Home Base location.
10.4 Reimbursement for Meals and Lodging. The Service Rates set forth in Section 9.1 and Exhibit D Compensation include meals and lodging for the number of Company Persons and those of Companys other contractors specified in Exhibit D Compensation. Meals and lodging for additional Persons shall be at the rate specified in Exhibit D Compensation.
11. FINANCIAL MATTERS
11.1 Contractors Invoices.
(A) Contractor shall invoice Company in advance, 10 days prior to the Drilling Units anticipated arrival on location, for the amount of USD 6.30 million (the Advance Payment Invoice). Thereafter, Contractor shall send invoices every
fourteen (14) days in the amount of USD 3.15 million to Company at the Company address set forth in Exhibit D Compensation. The invoices of USD 3.15 million sent to the Company shall contain a detailed calculation containing Company approved timesheets, equipment sheets and shipping manifests where applicable, and shall be submitted in accordance with the provisions set for in this Section 11.1. in support of the work performed during the previous period.
(B) At the end of each Well, Contractor shall invoice or credit Company for any positive or negative variances for all rates, fees, and reimbursements, etc. as specified in this Agreement. Clause 11.2 B does not apply to this clause 11.1 B.
(C) Contractor shall include all of the following information in every invoice:
(1) The title and number of this Contract.
(2) The amount due in the Currency.
(3) If applicable, all the following:
(a) The amount of local currency due.
(b) Transaction Taxes which Contractor proposes to collect or for which it will seek reimbursement from Company (including a tax assessed against Company but collected by Contractor).
(c) Contractors tax registration number(s).
(D) Company shall provide to Contractor, if available, an exemption certificate, a letter from the appropriate authority or a letter from Company agreeing that Company will self-assess and remit Transaction Taxes (e.g., VAT, GST, sales tax, etc.) for one or more relevant taxing jurisdictions (instead of payment to Contractor), and Contractor shall not invoice Company for those taxes identified in the exemption certificate or letter.
11.2 Invoice Payments. Company shall pay Contractors invoices as follows:
(A) Payment Timing. Company shall pay undisputed invoice amounts within ten (10) days from the date of each invoice. Additional terms concerning an accelerated payment discount may be set out in Exhibit D Compensation.
(B) Termination for Non-payment. If Company fails to make payment of an undisputed invoice to Contractor within (10) days of receiving written notice of failure to pay the undisputed amount, Company shall be in repuditory breach of this Agreement and Contractor at its sole discretion will be entitled to terminate this Agreement, demobilize and leave the Area of Operation. Any such termination by Contractor under this clause shall be treated as a termination for convenience by Company and Contractor shall be compensated pursuant to clause 3.7(C) of this Agreement.
(C) Right to Withhold Payments.
(1) If Company disputes all or part of an invoice Company shall within fifteen (15) days notify Contractor of the Dispute and pay the undisputed portion within thirty (30) days from the date of the invoice.
(2) If Company notifies Contractor of a Dispute in relation to part of a paper invoice, Company shall pay the disputed portion into an escrow account until the Dispute is resolved.
(D) Notification of Non-Payment of an Undisputed Invoice. If Contractor has not received payment of any undisputed invoice amount for more than thirty (30) days after Companys receipt of that invoice, Contractor may notify Company of this non-payment. If payment is not made within three (3) days Contractor shall charge, interest of LIBOR plus 5 basis points on any amount so outstanding until the amount is paid in full.
(E) Banking Regulations and Currency Requirements. Subject to all Applicable Laws, including banking and currency laws, Company shall pay undisputed Contractors invoices as follows:
(1) Company shall pay funds to Contractor by electronic funds transfer to the account of Contractor as set out in Exhibit D Compensation.
(2) Company shall make all payments in the Currency (including expenses paid in other currencies that Contractor has converted as required by this Contract and invoiced in the Currency) except as required in Section 11.2(D)(3).
(3)
11.3 Subordination of Lien Rights by Company. Company may not impress any Liens on the Drilling Unit superior to Contractors mortgagers and other financial documents. Arising out of this Contract, Company shall not create or allow its contractors to attach any Lien upon the Drilling Unit. Should the Drilling Unit be arrested or detained by reason of a Lien place on it by Company or its contractors, Company shall take all reasonable steps, at its risk and expense, to secure the prompt release of the Drilling Unit, including establishing appropriate security or bonds. Nothing in this provision shall be deemed to prevent Company from asserting any maritime Liens against Drilling Unit that may arise by operation of law, but that Lien shall be fully subordinated to Contractors mortgages and any other financial documents.
12. ADDITIONAL OBLIGATIONS
12.1 Compliance with Applicable Laws. Without limiting any other provision in this Contract, both Parties shall comply with, and shall ensure that all members of their respective groups comply with, all Applicable Laws, concessions and clearances, including those of the Country. Nothing in this Contract requires either Party to comply with Applicable Laws if that requirement would be inconsistent with U.S. and UK anti-bribery and anti-boycott laws.
12.2 Improper Influence. The Parties represent and warrant that, in connection with this Agreement or the business resulting therefrom:
a. it is knowledgeable about anti-bribery Laws, including the United States Foreign Corrupt Practices Act of 1977 and the United Kingdom Bribery Act 2010 (as amended from time to time) and all other applicable national, regional, provincial, state, municipal or local laws and regulations that prohibit the bribery of, or the providing of unlawful gratuities, facilitation payments or other benefits to any official or employee of any government, or any agency, ministry, department of a government (at any level), person acting in an official capacity for a government regardless of rank or position, official or employee of a company wholly or partially controlled by a government (for example, a state owned oil company), political party and any official of a political party; candidate for political office, officer or employee of a public international organization, such as the United Nations or the World Bank, or immediate family member (meaning a spouse, dependent child or household member) of any of the afore-mentioned or any other person or company (a Government Official), which are applicable to the performance of this Agreement and will actively and fully comply with all such laws; and
b. neither it nor a Related Party have made, offered or authorized or will make, offer or authorize any payment, gift, promise or other advantage, whether directly or through any other person or entity, to or for the use or benefit of any Government Official or any person or any Cal Dive or any undertaking where such payment, gift, promise or other advantage would (i) comprise a facilitation payment (a payment made to facilitate or expedite performance of a commonly performed, routine governmental action); and/ or (ii) violate the anti-bribery Laws.
The Parties undertake to immediately notify the other if in connection with this Agreement or the business resulting therefrom it receives or becomes aware of any request from a Government Official or any person or an employee of a Party or any undertaking for any payment, gift, promise or other advantage of the type mentioned in this Clause.
Parties represent and warrant that neither it nor any of its related parties is a Government Official or other person who could assert illegal influence on behalf of the Parties. If any of the foregoing becomes a Government Official, a Party shall promptly notify the other Party.
The Parties shall save, indemnify, defend, and hold harmless each other from and against any and all claims arising out of a Partys representations herein being untrue or arising out of a Partys breach of any of its warranties or undertakings in this Clause.
12.3 No Penalty for Compliance. Company may not terminate this Contract in the event Contractors breach or violation of any provisions of this Contract results from Contractors refusal to fulfill a request, whether direct or indirect, explicit or otherwise, for an Improper Benefit. For purposes of this Section 12.3, the term Improper Benefit means any payment, promise or offer to pay or authorization of the payment of any money gift, or other thing of value of any nature including but not limited to direct or indirect payments, gifts, entertainment, travel expenses, political or charitable contributions, or services, to any Government Official, or to any third party at the request of or for the benefit of any Government Official, for purposes of (i) influencing any act or
decision of such Government Official in his official capacity, (ii) inducing such Government Official to do or omit to do any act in violation of the lawful duty of such Official; (iii) securing any improper advantage; or (iv) inducing such Government Official to use his influence with the Government or instrumentality thereof to affect or influence any act or decision of the Government or such instrumentality with respect to any activities undertaken relating to this Contract.
13. RECORDS AND INSPECTION
13.1 Records. Contractor shall establish and maintain all Records which are necessary and appropriate in accordance with good management practice (under the circumstances of this Contract) to facilitate an accurate and complete record of all of the performance by Contractor of its obligations under this Contract.
13.2 Retention of Records. All Records required to be kept by Section 13.1 shall be maintained and retained by Contractor Group until at least twelve (12) months from the end of the calendar year in which this Contract is completed or terminated. All Records required to be kept by Section 13.1 shall be maintained in either paper or electronic format.
14. TAXES
14.1 Contractors Taxes. Contractor is solely responsible for the following taxes levied against Contractor relating to the Services or this Contract outside of Guinea:
(A) Income/Franchise. Income, withholding, excess profit or other taxes, charges or imposts assessed or levied on account of Contractors earnings, taxable margins or receipts (including gross receipts), or franchise taxes for the privilege or actual conduct of business that are measured by Contractors net worth, capital, surplus or undivided profits.
(B) Personnel. Taxes assessed or levied against or on account of compensation or other benefits paid to Contractors employees.
(C) Property. Taxes assessed or levied against or on account of, or by reference to the value of, any property or equipment (including materials and consumable supplies) of Contractor except Import/Export Charges reimbursable by Company under Section 15.6.
(D) Services. Taxes assessed or levied against or on account of, or by reference to the value of, the Services or this Contract.
14.2 Companys Taxes. Company is responsible for all taxes levied against Company relating to the Services or this Contract.
14.3 Gross-Up for Withholding Tax - The Service Rates included in Exhibit D Compensation are not inclusive of Contractors Taxes. If Company is required to withhold income tax on payments made to Contractor, such payments shall be grossed-up such that Contractor receives payments equal to the Service Rates included in Exhibit D Compensation after the application of withholding tax.
14.4 Reimbursement of Companys Taxes. With the exception for amounts included in Section 14.3 above, Company shall reimburse Contractor for all documented Contractors Taxes related to the Services or this Contract in Guinea, and Company shall indemnify, defend and hold Contractor harmless from the payment of all Taxes or related charges of any nature whatsoever, imposed or assessed by the Government in Guinea. However, in the event that Company is unable to use or loses its tax exemptions due solely to Contractors Gross Negligence, Contractor shall be responsible for its Guinean tax liability only to the extent of the exemptions lost.
14.5 Transaction Taxes. If any Transaction Taxes are applicable, these taxes shall be separately itemized and identified on Contractors invoices as provided in Section 11.1; paid by Company and collected by Contractor and paid over by Contractor to the appropriate governmental agency in accordance with Applicable Laws (except to the extent Company advises Contractor pursuant to Section 11.1(C) that in accordance with Applicable Laws, Company will be responsible for self-assessing and paying these taxes). Each Party shall provide the other Party on a timely basis with invoices, tax receipts and any other documentation that may be required for Company or Contractor to obtain tax reimbursement, credit, abatement or refund of any taxes.
14.6 Subcontractor Taxes. Each Party is solely responsible for all liabilities or Claims for taxes assessed or levied with respect to actions (or omissions to act) of such Partys Subcontractors, their directors, officers, employees or agents in relation to this Contract or the Services.
14.7 Tax Records. Company will provide Contractor with any information which Contractor may reasonably require in order to file any required tax returns in accordance with appropriate Laws.
15. IMPORT/EXPORT OBLIGATIONS.
15.1 Definitions Relating to Import/Export Obligations.
(A) Import/Export Charges means customs or import or export duties or taxes, and all other charges related to port or customs clearances, including pilotage, agent fees, brokerage fees, handling charges and port dues.
(B) Contractor Import/Export Items means any property, goods, materials or equipment that Contractor imports into the Country or the Area of Operations (whether permanently or temporarily) in order for Contractor to perform the Services.
(C) Company Import/Export Items means any property, goods, materials or equipment that Company imports into the Country or the Area of Operations (whether permanently or temporarily) in connection with this Contract.
(D) Import/Export Exemptions means exemptions from or reductions of Import/Export Charges obtained by Company or available to Contractor or members of Contractor Group.
15.2 Contractor Imports and Exports. Contractor is responsible for all of the following:
(A) For exporting all Contractor Import/Export Items from their country of origin (including deemed exports of software, technology or other intellectual property).
(B) For importing all Contractor Import/Export Items into the Country and the Area of Operations.
(C) For obtaining all necessary permits, licenses, authorizations and clearances for the export and import of Contractor Import/Export Items.
(D) For complying with all Applicable Laws, including those of the country of export and the country of origin.
15.3 Company Imports and Exports. Company is responsible for all of the following:
(A) For exporting all Company Import/Export Items from their country of origin (including deemed exports of software, technology or other intellectual property).
(B) For importing all Company Import/Export Items into the Country and the Area of Operations.
(C) For obtaining all necessary permits, licenses, authorizations and clearances for the export and import of Company Import/Export Items.
(D) For complying with all Applicable Laws, including those of the country of export and the country of origin.
15.4 Import/Export Exemptions. Contractor and Company shall use its best efforts and take all actions necessary to ensure that all possible Import/Export Exemptions are obtained, and that all requirements for Import/Export Exemptions are complied with. Neither Party shall take any action that is prejudicial to obtaining any available Import/Export Exemption.
15.5 Payment of Import/Export Charges. Contractor shall pay all Import/Export Charges, on Contractor Import/Export Items subject to reimbursement under Section 15.6, if applicable. All temporary import bonds shall be administered by Contractor and provided at Companys sole cost.
15.6 Reimbursement. If an Import/Export Exemption is not available through no fault of Contractor, then Company shall reimburse Contractor for the actual documented cost of any Contractor Import/Export Charges that are paid by Contractor to a duly authorized representative of the government having jurisdiction.
15.7 Exports after Completion of the Services. Contractor is responsible for obtaining all necessary permits, licenses, authorizations and clearances for the export from the Country or the Area of Operations, and the import into the destination country, of any Contractor Import/Export Items which are exported from the Country or the Area of Operations.
16. CLAIMS, LIABILITIES AND INDEMNITIES
16.1 INTENT OF INDEMNITY PROVISIONS. The Parties agree to allocate between them responsibility for all Claims as set out below. As used in this Section 16, the following terms have specified meanings.
(A) Fault means the active, passive, sole, contributory, concurrent or gross negligence of a Person, the unseaworthiness of any vessel, including the Drilling Unit, strict liability, or breach of warranty.
(B) Gross negligence means willful and wanton disregard for harmful, foreseeable and avoidable consequences.
(C) An occurrence is defined as an accident, including continuous or repeated exposure to substantially the same general harmful conditions.
(D) Third Parties includes any Person who is not a member of the Contractor Group, the Company Group.
(E) Indemnify, indemnifies, indemnity obligations, and similar terms mean waive, assumes responsibility for, releases indemnifies and holds harmless.
(F) Losses contemplated by this Section 16 include the cost of removal of wreckage.
16.2 CONTRACTOR GROUPS PROPERTY.
(A) General. Subject to the provisions of Sections 16.2(B) and 16.2(B)(4), if damage is suffered or loss is incurred to Property of the Contractor Group, including the Drilling Unit, where that damage or loss arises out of this Contract or the Services, Contractor indemnifies Company Group against that damage or loss from and against Claims by the Contractor Group for that damage or loss regardless of fault of Company Group.
(B) Damage or Loss to Downhole Equipment. Company shall reimburse Contractor for damage to or loss of the Downhole Equipment owned or provided by Contractor while in the hole below the rotary table. Company shall pay Contractor the lesser of the repair cost or the replacement cost for Downhole Equipment in accordance with the provisions below:
(1) If the Downhole Equipment component is new at the Commencement Date of the Contract:
(a) During the first twelve (12) months of the term of the Contract replacement cost;
(b) During the second twelve (12) months of the term of the Contract ninety-five percent (95%) of replacement cost; and
(c) Thereafter eighty-five percent (85%) of replacement cost.
(2) If the Downhole Equipment component has been in service for a period of twelve (12) months at the Commencement Date of the Contract or at the time it replaces previously damaged components eighty-five percent (85%) of replacement cost.
(3) If used Downhole Equipment component is replaced during the Term of the Contract with new Drill String components:
(a) During the first twelve (12) month period following replacement replacement cost;
(b) During the second six (6) month period following replacement ninety percent (90%) of replacement cost; and
(c) Thereafter eighty-five percent (85%) of replacement cost.
(4) Reimbursement by Company under this Section 16.2(B) is based on Contractors actual documented cost to repair or replace the damaged components, plus, if shipped to the Area of Operations, actual documented freight, duties (reimbursement of duties being subject to Section 15.6) and handling costs incurred by Contractor for transport of the replacement components to the Company Operations Base.
(C) Damage to Subsea Equipment.
(1) Company shall reimburse Contractor for damage or loss to Contractors Subsea Equipment as a result of loop, eddy or other adverse currents or named tropical storms / hurricanes that cause the Subsea Equipment to exceed its technical capabilities, subject to the following:
(a) Contractor shall, as soon as reasonably practical, notify Company if Contractor discovers that the currents exceed or may exceed the technical limitations of the Subsea Equipment.
(b) If such currents are not discovered by Contractor, or if discovered and Company nevertheless instructs Contractor to proceed and damage to the Subsea Equipment results, Contractor shall advise Company of such damage once known, but Contractor shall nevertheless be entitled to reimbursement under this Section 16.2(B)(4).
(c) If Contractor advises Company of such currents and Company requests Contractor to proceed with Services, refusal by Contractor to proceed with Services despite Companys request will not be considered breach of any provision of the Contract.
(2) Company shall reimburse Contractor for damage or loss to Contractors Subsea Equipment as a result of the Drilling Unit being moved outside a one hundred and fifty foot (150) radius from the well center while the subsea equipment is suspended below the rotary table at Companys request (also known as well hopping). Furthermore, Contractor shall not be required to move the Drilling Unit outside a one hundred and fifty foot radius from the well center with the subsea equipment suspended below the rotary table and Contractors refusal to do so will not be considered a breach of any provision of this Contract
(3) Company shall reimburse Contractor for damages to Contractors Subsea Equipment as set forth in Section 16.2(C) in an amount equal to the then current replacement cost of the Subsea Equipment, plus delivery to the Drilling Unit, or the repair cost, whichever is less. If this damage or loss causes any downtime for the Drilling Unit, Company shall, in addition, pay Contractor at the Standby Rate until repair is completed.
16.3 COMPANY GROUPS PROPERTY. With respect to loss or damage to Property of Company Group, Company indemnifies Contractor Group from and against Claims for damage or loss to Property of Company Group where that damage or loss arises out of this Contract and the Services regardless of Fault of Contractor Group.
16.4 INJURY OR DEATH.
(A) Contractor Groups Employees. Contractor indemnifies Company Group from and against Claims for injury to or death of Contractor Group employees where that injury or death arises out of this Contract or Services regardless of Fault of Company Group.
(B) Company Groups Employees. Company indemnifies Contractor Group from and against Claims for injury or death of Company Group employees where that injury or death arises out of this Contract regardless of Fault of Contractor Group.
16.5 LIMITATION ON LIABILITY FOR WELL EVENT CONTROL COSTS. If a Well Event arises out of this Contract, Company releases and indemnifies each member of Contractor Group from and against Claims for Well Event Control Costs.
16.6 THIRD PARTY INDEMNITY
(A) Company indemnifies Contractor Group from and against Claims for injury or death or loss or damage to property of Third Parties arising out of this Contract, but only to the extent caused by the Fault of Company Group.
(B) Subject to the provisions of Section 16.6(C), Contractor indemnifies Company Group from and against Claims for injury or death or loss or
damage to property of Third Parties arising out of this Contract, but only to the extent caused by the Fault of the Contractor Group.
(C) Company indemnifies Contractor Group from and against Claims for loss of or damage to underwater structures, equipment, or obstructions owned by Third Parties arising out of this Contract that occur when the Drilling Unit is being moved with the Subsea Equipment suspended below the rotary table at Companys request.
(D) Company indemnifies Contractor Group from and against Claims for loss of or damage to underwater structures, equipment, or obstructions owned by Third Parties arising out of this Contract that occur when the Drilling Unit is being moved between wellheads with the Subsea Equipment suspended below the rotary table at Companys request.
16.7 POLLUTION DAMAGE.
(A) Contractor indemnifies Company Group from and against Claims arising out of this Contract for control, cleanup, removal, assessments, damage to natural resources, and Third Party property damage or loss from Pollution that originates above the water level from spills of fuels, lubricants, motor oils, non-oil based drilling fluids, pipe dope, paints, solvents, ballast, bilge and garbage within Contractors possession and control and directly associated with the Drilling Unit.
(B) Except as provided in Section 16.7(A), Company indemnifies Contractor Group from and against Claims arising out of this Contract for control. cleanup, removal, assessments, damage to natural resources, and Third Party property damage or loss from Pollution, including Pollution that originates at or below the water level.
16.8 LOSS OF WELLBORE AND RESERVOIR DAMAGE. If the wellbore, i.e. the hole below the seabed, is lost or damaged at any time, Company indemnifies the Contractor Group from and against Claims arising out of this Contract for damage to or loss of the wellbore and reservoir. Company indemnifies the Contractor Group from and against Claims arising out of this Contract for the cost of regaining control of any wild well. Company indemnifies the Contractor Group from and against Claims arising out of this Contract for injury to, destruction of, or loss or impairment of any property right in or to oil, gas or other mineral substance or water, if at the time of the act or omission causing such injury, destruction, loss, or impairment, said substance had not been reduced to physical possession above the seabed, and for any loss or damage to any formation, strata, or reservoir beneath the seabed.
16.9 USE OF MEDICAL FACILITIES OR MEDICAL EVACUATION. Company indemnifies Contractor from and against Claims for injury to or death of members of Company Group that arise out of or in connection with the recovery, diagnosis, treatment or medical evacuation of such personnel, or the provision of pharmaceutical products or medical supplies furnished or rendered by Contractor Group. Contractor indemnifies Company Group from and against Claims arising
out of Company making available to Contractor Group access to emergency evacuation services pursuant to Section 8.2.
16.10 INDEMNITY FOR TAXES. Each Party indemnifies the other Party from and against Claims for taxes (including interest and penalties), costs, losses, duties or charges, that any taxing authority may assess or levy against such Party in connection with such Partys tax obligations relating to this Contract or arising out of such Partys actions or failure to act. Company indemnifies Contractor Group from and against any Claim arising from Companys failure to provide the information referred to Section 11.1(D) or from erroneous information referred to in Section 14.5.
16.11 LIMITATIONS ON CLASSES OF DAMAGES. Company and Contractor waive and release each other, Contractor Group and Company Group from and against, directly or indirectly, to the fullest extent permitted by applicable law, all of the following Claims for damages arising out of this Contract or the Services, whether such Claims are made in connection with an indemnity specified in this Section 16, a breach of any obligation under this Contract or otherwise:
(A) Indirect, incidental or consequential loss.
(B) Loss or delay of production, including production of petroleum or petroleum products, or loss of or damage to the leasehold, loss of hole, loss of reservoir, or loss of delay in drilling or operating rights.
(C) Loss of prospective economic advantage or benefit.
(D) Loss of profits or revenue, costs or expenses resulting from business interruptions, loss of business opportunity, loss or damage to property, equipment, materials, and services.
(E) Costs of Persons hired by the Parties, including Subcontractors, to provide vessels, materials, and services or work in support of the Services, sometimes referred to as spread costs.
(F) Punitive or exemplary damages.
16.12 EXTENT OF WAIVER, RELEASE AND INDEMNITY OBLIGATIONS. The indemnity obligations of Contractor and Company and the limitations and exclusions of damages set out in this Section 16 shall apply regardless of the Fault of any Person indemnified or relieved of damages, any other anticipated or unanticipated event or condition, or any other legal theory of liability whether in contract, tort, or otherwise, and regardless of whether pre-existing the execution of this Contract, and regardless of whether liability of any kind is imposed or sought to be imposed on any Person indemnified or relieved of damages.
16.13 DEFENSE OF CLAIMS.
(A) Contractor shall, at its sole cost and expense, be responsible for Defense Costs relative to Claims which may be brought against Company Group for which Contractor wholly releases and/or indemnifies Company Group.
Contractor shall accept and initiate such defense within thirty (30) days of written request by Company.
(B) Company shall, at its sole cost and expense, be responsible for Defense Costs relative to Claims which may be brought against Contractor Group for which Company wholly releases and/or indemnifies Contractor Group. Company shall accept and initiate such defense within thirty (30) days of written request by Contractor.
(C) In instances where a Partys indemnity obligations are limited to a certain amount or percentages of damages, Defense Costs shall ultimately be borne by the Parties in proportion to their respective obligation to contribute to any settlement or judgment related to the underlying Claim. The primary party responsible for indemnification shall fund all Defense Costs until such time as a settlement is finalized or judgment is rendered, with the reconciliation between the Parties being conducted thereafter.
16.14 DURATION OF INDEMNITY, RELEASE AND DEFENSE OBLIGATIONS.
(A) The indemnity obligations in this Section 16 shall be effective as of the Effective Date of this Contract and shall remain in effect until termination.
(C) Notwithstanding the provisions of Section 16.14(A), the indemnity obligations under this Section 16 shall continue to be in effect after termination of the Contract for any of the following:
(1) Claims arising during the Term of the Contract regardless of whether such claims are initiated during or after the Term of the Contract; or
(2) Claims arising during removal of wreckage operations under Section 2.12.
17. INSURANCE.
Contractor shall maintain insurance required by Applicable Laws and as provided in Exhibit C Insurance.
18. OWNERSHIP OF INTELLECTUAL PROPERTY.
18.1 Confidentiality of Contract Information.
(A) Contractor shall treat Company Contract Information as valuable, proprietary and confidential information and shall ensure that all members of Contractor Group do not disclose, any Company Contract Information to any other Person without the prior written consent of Company.
(B) Company shall treat Contractor Contract Information as valuable, proprietary and confidential information and shall ensure that all members of Contractor Group do not disclose, any Company Contract Information to any other Person without the prior written consent of Company.
18.2 Ownership of Contract Information
(A) All intellectual property rights and all other Property and other rights in relation to Company Contract Information are owned by Company. To the extent that Contractor or other members of Contractor Group discovered, developed or created copyright or other intellectual property or other rights arise in relation to that Company Contract Information, those works and rights are work made for hire under this Contract and are the exclusive property of Company.
(B) All intellectual property rights and all other Property and other rights in relation to Contractor Contract Information are owned by Contractor. To the extent that Contractor or other members of Contractor Group discovered, developed or created copyright or other intellectual property or other rights arise in relation to that Contractor Contract Information, those works and rights are the exclusive property of Contractor.
18.3 Grant of License to Company. Company and its Affiliates shall have an irrevocable, non-exclusive, royalty-free, perpetual, worldwide right and license, to use Contractor Contract Information to the extent necessary to exploit Services or Products provided under this Contract, provided that Company and its Affiliates ensure that a receiving party of the Contractor Contract Information acknowledges its confidential and proprietary nature and undertakes to safeguard such Contractor Contract Information using at the least the same degree of care undertaken by Company herein..
18.4 Grant of License to Contractor. Contractor is hereby granted an irrevocable, worldwide, royalty-free license to use Company Contract Information in any manner and disclose within its normal operations to perform the Services required to be performed by the Drilling Unit under this Contract, provided that Contractor and its Affiliates ensure that a receiving party of the Company Contract Information acknowledges its confidential and proprietary nature and undertakes to safeguard such Company Contract Information using at the least the same degree of care undertaken by Contractor herein.
19. BUSINESS RELATIONSHIP
19.1 Contract for Services. This is a maritime contract for maritime services and is not a charter or lease of Contractors Drilling Unit or other equipment.
19.2 Independent Contractor. The Services are provided by Contractor as an independent contractor, and Contractor and the members of Contractor Group are not employees, agents or representatives of Company or Company Group. Company shall have no direction or control of Contractor Group except in the results to be obtained.
19.3 Control over Performance. As an independent contractor, Contractor has complete control, supervision and direction over its equipment and personnel and over the manner and method of the performance of the Services.
20. ASSIGNMENT
20.1 Assignment by Contractor. Contractor may not assign or transfer in whole or part its rights and obligations under this Contract to any Person other than an Affiliate of Contractor or other than a financing bank, or in the event of a reorganization, merger,
consolidation or asset sale, to any other entity which assumes the assets of Contractor under that reorganization, merger, consolidation or asset sale without the prior written consent of Company. Any attempted assignment or transfer in breach of this obligation is void as between Company and Contractor.
20.2 Assignment by Company. Company may assign or transfer all or part of its rights or obligations under this Contract as follows:
(A) Without Contractors consent to an Affiliate of Company.
(B) Without Contractors consent to any other Person in the event of a reorganization, merger, or consolidation, to any other entity which assumes the assets of Company under that reorganization, merger, or consolidation.
(C) To any other Person with Contractors consent.
20.3 Successors and Assigns. This Contract upon assignment in accordance with Section 20.1 or 20.2 will be binding and will insure to the benefit and obligation of the successors and assigns of the assigning Party.
21. FORCE MAJEURE
21.1 Definition of Force Majeure Event. Force Majeure Event means any of the events or circumstances described in this Section 21.1 that are beyond the control of an affected Party and which prevents the performance of any of the affected Partys obligations under this Contract after that Party has taken every reasonable step, including reasonable expenditures of money, to remedy the impact of the event: Events or circumstances that may give rise to a Force Majeure Event are limited to the following:
(1) Earthquakes, fires, storms, tidal waves, tsunami, floods or other physical natural disasters, including epidemic disease outbreaks such as typhoid, yellow fever, Ebola, etc.
(2) Acts of war (whether declared or undeclared), terrorism, riot, piracy, civil war, blockade, insurrection or civil disturbances.
(3) Acts of a governmental entity, agency or other local authority.
(4) Strikes or labor disputes.
21.2 Excuse of Performance due to a Force Majeure Event. Subject to compliance with Section 21.3, neither Party is liable for any delay in performing or failure to perform its obligations under this Contract (excluding release, indemnity and defense obligations and the obligation to pay undisputed invoices) if and to the extent that the delay or failure is caused by a Force Majeure Event. A Party is excused from its performance obligations that are prevented by a Force Majeure Event for as long as the Force Majeure Event continues.
21.3 Notice and Mitigation. If a Party seeks relief from its obligations to perform under this Contract under Section 21.2, it shall:
(A) Give prompt notice to the other Party, which must include all of the following information:
(1) The event that the Party considers constitutes a Force Majeure Event; and
(2) A good faith estimate of the duration of the Force Majeure Event.
(B) Make all reasonable efforts to overcome the Force Majeure Event and to mitigate its effects.
(C) If the Force Majeure Event continues, give periodic notices in accordance with Section 21.3(A), with a frequency as directed by the other Partys Representative.
(D) Give the other Party prompt notice of the conclusion of the Force Majeure Event and resume performance of the Services as soon as reasonably possible after its conclusion.
21.4 Termination of the Contract due to a Force Majeure Event. This Contract may be terminated due to a Force Majeure Event in accordance with Section 3.3(B).
22. GOVERNING LAW AND RESOLUTION OF DISPUTES
22.1 Governing Law. This Contract is governed by and interpreted under the laws of England without regard to its choice of law rules. The United Nations Convention on Contracts for the International Sale of Goods, 1980 (known as the Vienna Sales Convention) does not apply to this Contract.
22.2 Resolution of Disputes. The Parties shall exclusively and finally resolve any Dispute between them using direct negotiations, mediation and arbitration as set out in this Section 22.
22.3 Direct Negotiations. If a Dispute arises, a Party may initiate the resolution process by giving notice setting out in writing and in detail the issues in Dispute and the value of the Claim to the other Party. A meeting between the Parties, attended by individuals with decision-making authority, must take place within thirty (30) days from the date the notice was sent in an attempt to resolve the Dispute through direct negotiations.
22.4 Mediation. If the Dispute cannot be settled by direct negotiations within thirty (30) days of initiation of the resolution process, either Party may initiate mediation by giving notice to the other Party. The mediation shall be attended by individuals representing each Party with decision-making authority and the place of mediation shall be Houston, Texas. Each Party to the mediation shall pay one-half the cost of the mediator.
22.5 Arbitration. If the Dispute is not resolved by mediation within thirty (30) days from the date of the notice requiring mediation, or if the Dispute is unresolved within sixty (60) days from the date of the notice requiring direct negotiations, then the Dispute shall be finally settled by binding arbitration and either Party may initiate such arbitration by giving notice to the other Party. The arbitration shall be conducted in accordance with the United Nations Commission on International Trade Law (UNCITRAL) Arbitration Rules, except to the extent of conflicts between the UNCITRAL Arbitration Rules and
the provisions of this Contract, in which event the provisions of this Contract prevail. The International Centre for Dispute Resolution is the appointing authority, London, England.
22.6 Arbitration Proceedings. The following provisions shall apply to any arbitration proceedings commenced pursuant to Section 22.5:
(A) The number of arbitrators shall be one (1) if the monetary value of the Dispute is Ten Million Dollars (US $10,000,000) (or its currency equivalent) or less. The number of arbitrators shall be three (3) if the monetary value is greater than Ten Million Dollars (US $10,000,000) or its currency equivalent.
(B) The arbitrator or arbitrators must be fluent in the English language and the language of the arbitral proceeding shall be English.
(C) The arbitrator or arbitrators must remain neutral, impartial and independent regarding the Dispute and the Parties. If the number of arbitrators to be appointed is one, that arbitrator, or the presiding arbitrator if the arbitrators are three, must be a lawyer experienced in the resolution of disputes with experience relating to the types of issues involved in the Dispute.
(D) The Parties waive any Claim for, and the arbitrator has or arbitrators have no power to award, the damages waived and released under Section 16.11.
(E) All arbitration fees and costs (except for translation costs) shall be borne equally regardless of which Party prevails. Each Party shall pay its own costs of legal representation and witness expenses.
(F) The arbitrator or arbitrators must render a reasoned award in writing within 30 days of the arbitration proceeding. The award is final and binding.
23. NOTICES, REPRESENTATIVES AND CONTACT INFORMATION
23.1 Notices.
(A) All notices required or permitted under this Contract must be in writing and delivered by mail (postage prepaid), overnight courier or by hand delivery to the address of the receiving Party set out in the signature page to this Contract. Notice may also be delivered by facsimile sent to the facsimile number of the receiving Party set out in the signature page to this Contract (or such other address as a Party may notify in writing) provided that the original notice is promptly sent to the recipient by mail (postage prepaid) or by hand delivery. Notices sent by email are ineffective.
(B) Notices are effective when received by the recipient during the recipients regular business hours.
(C) Notices which do not comply with the requirements of this Contract are ineffective, and do not impart actual or any other kind of notice.
23.2 Representatives and Contact Information.
(A) The representatives and contact information of each Party are as set out in the Exhibit A Scope of Work.
(B) Each Party may change its representative or contact information by giving notice to the other Party. If a notice is given under this Section 23.2(B), the replacement representative or contact information which is set out in the notice replaces the representative or contact information as set out in the Exhibit A Scope of Work.
24. THIRD PARTY RIGHTS
No Person who is not a party to this Contract has any rights under this Contract or may enforce any provision in this Contract except that members of the Contractor Group and the Company Group, respectively, shall have the benefit of the indemnity obligations provided in their favor in Section 16 and shall have the right to enforce those obligations.
25. GENERAL PROVISIONS
25.1 Prior Agreements. This Contract comprises the complete and exclusive agreement between the Parties regarding the subject matter of this Contract, and supersedes all oral and written communications, negotiations, representations or agreements in relation to that subject matter made or entered into before the Effective Date.
25.2 Amendment. No amendment to this Contract is effective unless made in writing and signed by authorized representatives of both Parties.
25.3 Waiver. Neither Partys failure to pursue remedies for breach of this Contract, or payment of invoices constitute a waiver by that Party of any breach of this Contract by the other Party or raise any defense against Claims against that other Party for breach of this Contract. The waiver or failure to require the performance of any covenant or obligation contained in this Contract or pursue remedies for breach of this Contract does not waive a later breach of that covenant or obligation.
25.4 Parent Company Guarantee. As a condition precedent to this Contract, and prior to commencement of the Services, Company shall provide Contractor with a Parent Company Guarantee in a form acceptable to Contractor, attached to this Contract as Exhibit F.
25.5 Severability. Each provision of this Contract is severable and if any provision is determined to be invalid, unenforceable or illegal under any existing or future law by a court, arbitrator of competent jurisdiction or by operation of Applicable Laws, this invalidity, unenforceability or illegality does not impair the operation of or affect those portions of this Contract that are valid, enforceable and legal.
25.6 Survival. Despite completion of the Services or termination of this Contract for any reason, all provisions in this Contract containing representations, warranties, releases, defense obligations and indemnities, and all provisions relating to tax, import/export/customs, Contractors invoices, audit, confidentiality, insurance, disclaimer of certain remedies, limitations of liability, ownership or use or return of Contract
Information, removal of wreckage, retention and inspection of Records, Dispute resolution and governing law, and all Claims which arose prior to completion or termination, survive indefinitely until, by their respective terms, they are no longer operative or are limited by an applicable statute of limitations.
25.7 Counterparts. This Contract may be executed in any number of counterparts, each of which will be deemed an original of this Contract, and which together will constitute one and the same instrument; provided that neither Party will be bound to this Contract unless and until both Parties have executed a counterpart.
25.8 Drafting. Preparation of this Contract has been a joint effort of the Parties and the resulting Contract must not be construed more severely against one of the Parties than against the other.
The remainder of the page intentionally left blank.
IMPORTANT NOTICE: THIS CONTRACT CONTAINS PROVISIONS REGARDING INDEMNITIES AND WARRANTIES THAT EXPRESS THE AGREEMENT OF THE PARTIES CONCERNING CLAIMS ARISING OUT OF THIS CONTRACT.
The Parties have executed this Contract in triplicate as evidenced by the following signatures of authorized representatives of the Parties:
COMPANY: |
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CONTRACTOR: | ||
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SCS Corporation Limited, a wholly owned subsidiary of Hyperdynamics Corporation |
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Pacific Drilling Operations Limited | ||
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Signature: |
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Signature: | ||
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/s/ Ray Leonard |
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/s/ C. J. Beckett | ||
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Name: |
Ray Leonard |
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Name: |
C. J. Beckett |
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Title: |
President & CEO |
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Title: |
CEO |
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ADDRESS FOR NOTICES: |
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ADDRESS FOR NOTICES: |
EXHIBIT A - SCOPE OF WORK
Company: |
Contractor: | |
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SCS Corporation Limited |
Pacific Drilling Operations Limited | |
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Area of Operations: |
Country: |
Well Location(s): |
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Guinea |
Republic of Guinea |
TBD |
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Company Representative: |
Contractor Representative: | |
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Forrest Estep |
Alan Breed |
Name of Drilling Unit: Pacific Bora
Point of Origin for the Drilling Unit: Nigeria
Port of Entry for the Drilling Unit (if applicable): Conakry
Mobilization Delivery Point for the Drilling Unit: One nautical mile from Companys first location in Republic of Guinea
Point for Demobilization for the Drilling Unit: One nautical mile from the last well location
Party Responsible for providing permissions necessary to enter the Area of Operations to operate at the well location, as per Section 2.2(B)(2):
Company: x Contractor: o
Initial Term of the Contract, as per Section 3.2(A): (choose one option)
· Term: One (1) well
Option to Extend the Initial Term of the Contract, as per Section 3.2(B)(1) and 3.2(B)(2):
Applicable: x Not Applicable: o
If Applicable, indicate agreed extension period:
For the time necessary for Contractor to drill an additional number of wells: Three (3) 1-Well Options For a period of time:
Further Extensions of the Term of the Contract, as per Section 3.2(C) with two hundred seventy days notice to Contractor:
Option Available: o Not Available: x
Earliest Date Drilling Unit may be available, as per Section 1.1, Commencement Date definition:
March 1st, 2017
Latest Date Drilling Unit must be available, as per Section 3.3(E):
April 15, 2017
Number of days after completion of the Services by which Drilling Unit must be removed from the Area of Operations, as per Sections 2.8, 2.10, and 9.1(I): 10 calendar days
Shake down Period number of days: 6.2(C )(3) & 6.2(C)(4):
Not applicable for this contract
Force Majeure Event number of consecutive days: (per Section 3.3(C) and 9.1(G):
Twenty days
Additional requirements prior to the Commencement Date, as per Section 1.1:
Applicable: o Not Applicable: x
If Applicable, indicate requirements: Company will have auditors join rig no later than commencement of mobilization and audit/inspection will be performed at the prevailing terms of this contract. The audit terms will be mutually agreed prior to January 1, 2017. The Contractor shall provide full access to the drilling unit and the records of maintenance associated with same. The deficiencies will be reported to both Company and Contractor. Contractor agrees to correct deficiencies in a timely manner and at Contractors expense. Timely Manner will be agreed at same time the audit terms are agreed.
Estimated Schedule for Inspection(s) of the Drilling Unit, as per Section 7.2(D)(3):
Certification of Drilling Unit: Equipment inspections as per class and regulatory requirements
None
Structural Inspection of Drilling Unit: Equipment inspections as per class and regulatory requirements
None
Estimated UWILD/Drydock Schedule of Drilling Unit: Equipment inspections as per class and regulatory requirements
None
Local HES policy attached, as per Section 5.2: |
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Local Drug/Alcohol/Search policy attached, as per Section 5.2: |
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Local Content &/or Workforce Nationalization requirements, as per Section: Not applicable |
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Port of Entry for Contractors Personnel, as per Section 1.1 (if applicable): To be determined by Company. |
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Contractors Personnel Rotation Schedule, as per Section 7.1(D): 35 day rotation |
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No. of days notice required under Section 9.1(F)(4) for Contractor to remobilize its personnel: 10 calendar days |
No. of hours allowed per month to effect repairs and preventative maintenance of equipment at the Operating Rate:
As per Sections 9.2(A)(1)(a) and per 7.2(C)(4): A total of twenty-four hours per month is allotted for repairs and preventative maintenance for Surface Equipment (non-accrued); after which compensation will revert to zero Service rate.
As per Section 9.2(A)(2)(a) and per 7.2(C)(4): A total of forty-eight hours per month is allotted repairs and preventative maintenance for Subsea Equipment (non-accrued); after which compensation will revert to zero Service rate.
The allowance as indicated above for Section 7.2(C)(4) and Section 9.2 are considered a single combined monthly allowance.
Period of Consecutive Days of Stoppage of Services even though Contractor is in compliance with the Required Standard of Performance :
Number of Consecutive days for Surface Equipment, as per Section 9.2(A)(1)(b):
Termination: Thirty days
Number of Consecutive days for Subsea Equipment, as per Section 9.2(A)(2)(b):
Termination: Forty-Five days
Number of Consecutive days of Stoppage of Services due to Contractor being out of compliance with the Required Standard of Performance: Thirty days
Variations of Rates due to Changes in Law or Regulation as per Section 9.5.
Applicable: o Not Applicable: x
If Applicable, indicate requirements:
Contractor personnel required to load/unload the supplies and materials on supply vessels in the Area of Operations, as per Section 2.16:
Yes: x (as required) No: o
Transportation arrangements for Contractors personnel, if different from those set forth in Section 6.1(E)(4): Not applicable.
The Drilling Unit, Ancillary Equipment and Personnel to be furnished by Contractor are detailed in the following Attachments:
Attachment A1 DRILLING UNIT AND ANCILLARY EQUIPMENT SPECIFICATIONS
Attachment A2 EQUIPMENT, SUPPLIES, MATERIAL AND SERVICES TO BE FURNISHED BY COMPANY AND CONTRACTOR
Attachment A3 PERSONNEL TO BE FURNISHED BY CONTRACTOR
Attachment A4 DRILLING UNIT INSPECTION AND ACCEPTANCE REQUIREMENTS
Attachment A5 CONTRACTOR SAFETY MANAGEMENT SYSTEM
The remainder of the page intentionally left blank.
ATTACHMENT A1 TO EXHIBIT A SCOPE OF WORK
Offshore Drilling Contract No. PBA 3
DRILLING UNIT AND ANCILLARY EQUIPMENT SPECIFICATIONS
1. Name of Drilling Unit: Pacific Bora
2. Maximum water depth of Drilling Unit capability, as per Section A.4: 10,000 ft.
(Capable of 10,000 feet, equipped for 10,000 feet.)
3. Drilling depth capability for the Drilling Unit, as per Section A.4: 37,500 ft.
4. Drilling Unit specification and specifications for Ancillary Equipment are provided herein:
The remainder of the page intentionally left blank.
BEGINNING OF EMBEDDED FILE(S)
The remainder of the page intentionally left blank.
RIG AND EQUIPMENT SPECIFICATIONS
PACIFIC BORA
PACIFIC BORA
INTERNATIONAL ASSOCIATION of DRILLING CONTRACTORS
STANDARD FORMAT EQUIPMENT LIST for DRILLSHIP UNITS
Rev |
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Issue date |
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Reason for issue |
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Prepared |
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Checked |
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Approved |
F1 |
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11/Aug/09 |
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Standardization |
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CvD |
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CvD |
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CvD |
F2 |
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11/Nov/09 |
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Handling Tools & Drill Pipe |
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CvD |
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CvD |
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CvD |
H1 |
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4/April/10 |
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Aux. equipment |
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CvD |
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CvD |
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CvD |
H2 |
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22/July/10 |
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Remove Pacific Mistral reference |
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CvD |
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CvD |
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CvD |
H3 |
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1/Sept/10 |
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Additional information |
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CvD |
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CvD |
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CvD |
H4 |
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23/May/13 |
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Added 2nd BOP + Updated Info |
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CN |
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CvD |
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CvD |
ATTACHMENT A1 Drilling Unit and Ancillary Equipment Specifications 28NOV16
These specifications are intended for general reference purposes only and are not guaranteed to be current.
RIG AND EQUIPMENT SPECIFICATIONS
PACIFIC BORA
TABLE OF CONTENTS
SECTION A - UNIT SPECIFICATIONS |
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A1 |
Main Dimensions / Technical Description |
Page |
5 |
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A2 |
Storage Capacities |
Page |
5 |
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A3 |
Propulsion / Thrusters |
Page |
6 |
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A4 |
Operational Capabilities |
Page |
6 |
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A5 |
Variable Loading |
Page |
7 |
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A6 |
Environmental Limits |
Page |
7 |
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A7 |
Mooring System |
Page |
7 |
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A8 |
Marine Loading Hoses |
Page |
9 |
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A9 |
Cranes, Hoists, and Materials Handling |
Page |
10 |
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A10 |
Helicopter Landing Deck |
Page |
13 |
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A11 |
Auxiliary Equipment |
Page |
13 |
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SECTION B - GENERAL RIG SPECIFICATIONS |
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B1 |
Derrick and Substructure |
Page |
15 |
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B2 |
Drawworks and Associated Equipment |
Page |
16 |
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B3 |
Derrick Hoisting Equipment |
Page |
17 |
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B4 |
Rotating System |
Page |
18 |
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SECTION C POWER SUPPLY SYSTEMS |
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C1 |
Rig Power Plant |
Page |
20 |
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C2 |
Emergency Generator |
Page |
22 |
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SECTION D DRILLSTRING EQUIPMENT |
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D1 |
Tubulars |
Page |
24 |
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D2 |
Handling Tools |
Page |
35 |
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D3 |
Fishing Equipment |
Page |
40 |
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SECTION E - WELL CONTROL/SUBSEA EQUIPMENT |
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E1 |
Lower Riser Diverter Assembly |
Page |
48 |
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E2 |
Primary BOP Stack |
Page |
48 |
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E3 |
Primary Lower Marine Riser Package |
Page |
51 |
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E4 |
Secondary BOP Stack |
Page |
51 |
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E5 |
Secondary Lower Marine Riser Package |
Page |
53 |
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E6 |
Primary Marine Riser System |
Page |
54 |
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E7 |
Secondary Marine Riser System |
Page |
57 |
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E8 |
Diverter BOP |
Page |
59 |
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E9 |
Subsea Support System |
Page |
60 |
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E10 |
BOP Control System |
Page |
61 |
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E11 |
Subsea Control System |
Page |
62 |
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E12 |
Acoustic Emergency BOP Control System |
Page |
63 |
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E13 |
Subsea Auxiliary Equipment |
Page |
63 |
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E14 |
Choke Manifold |
Page |
64 |
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E15 |
BOP Testing Equipment |
Page |
65 |
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E16 |
Wellhead Running / Retrieving / Testing Tools |
Page |
65 |
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SECTION F - MUD SYSTEM/BULK SYSTEM |
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F1 |
High Pressure Mud System |
Page |
67 |
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F2 |
Low Pressure Mud System |
Page |
69 |
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F3 |
Bulk System |
Page |
73 |
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SECTION G - CASING / CEMENTING EQUIPMENT |
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G1 |
Casing Equipment |
Page |
75 |
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G2 |
Cement Equipment |
Page |
78 |
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SECTION H - INSTRUMENTATION / COMMUNICATION |
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H1 |
Drilling Instrumentation at Drillers Position |
Page |
80 |
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H2 |
Drilling Parameter Recorder |
Page |
82 |
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H3 |
Instrumentation at Choke Manifold |
Page |
82 |
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H4 |
Standpipe Pressure Gauge |
Page |
82 |
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H5 |
Deviation Equipment |
Page |
82 |
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H6 |
Calibrated Pressure Gauges |
Page |
83 |
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H7 |
Rig Communication System |
Page |
83 |
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H8 |
Environmental Instrumentation |
Page |
84 |
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H9 |
DP, Vessel Control and Navigation Systems |
Page |
84 |
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H10 |
Radio Equipment |
Page |
89 |
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SECTION I - PRODUCTION TEST EQUIPMENT |
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l1 |
Burners |
Page |
93 |
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l2 |
Burner Booms |
Page |
93 |
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l3 |
Lines Required on Burner Booms |
Page |
93 |
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l4 |
Sprinkler System |
Page |
94 |
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l5 |
Fixed Lines for Well Testing |
Page |
94 |
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I6 |
Auxiliary Power Availability |
Page |
95 |
SECTION J - WORKOVER TOOLS |
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J1 |
N/A |
Page |
96 |
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SECTION K ACCOMMODATION |
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K1 |
Offices |
Page |
97 |
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K2 |
Living Quarters |
Page |
97 |
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SECTION L - SAFETY EQUIPMENT |
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L1 |
General Safety Equipment |
Page |
99 |
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L2 |
Gas / Fire / Smoke Detection |
Page |
100 |
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L3 |
Fire Fighting Equipment |
Page |
102 |
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L4 |
Breathing Apparatus |
Page |
104 |
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L5 |
Emergency First Aid Equipment |
Page |
105 |
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L6 |
Helideck Rescue Equipment |
Page |
106 |
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L7 |
Rig Safety Store |
Page |
107 |
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L8 |
Emergency Warning Alarms |
Page |
107 |
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L9 |
Survival Equipment |
Page |
108 |
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SECTION M - POLLUTION PREVENTION EQUIPMENT |
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M1 |
Sewage Treatment |
Page |
110 |
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M2 |
Garbage Compaction |
Page |
110 |
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M3 |
Garbage Disposal / Grinder |
Page |
110 |
A. UNIT SPECIFICATIONS |
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Rig type: |
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6th Generation Ultra-Deepwater Drillship |
Unit/Design/Shape: |
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Samsung 10000 Double-Hull DP Drillship |
Unit flag: |
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Liberia |
Port of Registry |
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Monrovia |
Call Sign |
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A8WH8 |
Official Number |
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14745 |
Unit classification: |
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ABS, XA1E, Drilling Unit, XAMS, XACCU, DLA, XDPS-3, NBLES. |
IMO Certification: |
yes/no |
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Yes |
Which code version: |
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MODU Code 1989 ammended to 2001 |
Year of Construction: |
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Pacific Bora 2010 |
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Pacific Mistral 2011 |
Construction Yard: |
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Samsung Heavy Industries - Geoje, South Korea |
Type of Positioning system |
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Dynamic Positioning DP3 Class |
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Kongsberg Simrad SDP-32 as per ABS XDPS-3 |
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A.1 MAIN DIMENSIONS & TECHNICAL SPECS |
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Deadweight (light ship): |
mt |
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36,000 (per design) |
Maximum Loaded Displacement |
mt |
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96,000 (per design) |
Maximum Variable Deck Load |
mt |
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20,000 |
Draft at loadline (deepest): |
m |
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12 |
Overall length of unit (including anchor racks): |
m |
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228.0 |
Length Between Perpendiculars |
m |
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219.4 |
Overall width of unit (including anchor racks): |
m |
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42 |
Forward deck dimensions |
m x m |
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29.5 x 37.6 |
Aft deck dimensions |
m x m |
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63.3 x 37.6 |
Main deck elevation above baseline: |
m |
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19 |
Number of main columns/diameter: |
no x m |
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N/A |
Number of small columns/diameter: |
no x m |
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N/A |
Drilling draft/related displacement: |
m/mt |
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12.0 / 96,000 Tonnes |
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(Note not including 5.82m Thruster below keel) |
Transit draft/related displacement: |
m/mt |
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8.5 / 66,500 Tonnes |
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(Note not including 5.82m Thruster below keel) |
Moon pool dimensions: |
m x m |
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28.8 x 12.48 (length x width) |
Maximum opening through moon pool: |
m |
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28.8 x 10.48 |
Pontoon length: |
m |
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N/A |
Pontoon breadth: |
m |
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N/A |
Pontoon height: |
m |
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N/A |
Maximum Setback, Rotary & Hook Load |
lbs |
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5,640,000 |
Fuel Consumption (ave drilling) |
m3/day |
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Estimate 55 |
Accommodation for max. no. of personnel |
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200 persons |
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A.2 STORAGE CAPACITIES |
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Heavy Fuel or Diesel Oil tank |
m3 |
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5,700 (35,850 bbls) |
Diesel Oil Tank |
m3 |
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500 (3,140 bbls) |
Lube Oil Tank |
m3 |
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120 (750 bbls) |
Drilling water |
m3 |
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2,600 (16,350 bbls) |
Potable water |
m3 |
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1,300 (8,175 bbls) |
Active liquid mud |
bbl |
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5,500 + 500 (2 chemicals + 2 slugs) (max 18.2PPG) |
Reserve liquid Mud |
bbl |
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6,000 + 3,000 (Reserve or Waste)(max 18.2 PPG) |
Brine Storage Tank (Heavy brine) |
bbl |
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5,000 |
Crude Oil |
m3 |
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N/A |
Base Oil Tank |
bbl |
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5,000 |
Bulk bentonite |
m3 |
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113 (3,990 cu.ft) | |
Bulk barite |
m3 |
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339 (11,972 cu.ft) | |
Bulk cement |
m3 |
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452 (15,962 cu.ft) | |
Sacks storage |
sacks |
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10.000 | |
Pipe racks area |
m2 |
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795 | |
Load bearing capacity |
kg/m2 |
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2,164 | |
Riser racks area: |
m2 |
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730 | |
Load bearing capacity: |
kg/m2 |
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5,600 | |
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Miscellaneous storage area: |
m2 |
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Net area at the deck/casing rack for production riser, etc. and 351 m2 intended for miscellaneous equipment. | |
Ballast system |
m3 |
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68,500 | |
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A.3 PROPULSION & THRUSTERS |
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A.3.1 In-line Propulsion |
yes/no |
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No |
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Shafts: |
no. |
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N/A |
Motors per shaft: |
no. |
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N/A |
Motors make/type: |
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N/A |
Total HP per shaft: |
hp |
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N/A |
Propeller type (fixed/variable blade): |
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N/A | |
Nozzled: |
yes/no |
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N/A | |
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A.3.2 Thrusters |
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Quantity: |
no. |
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6 | |
Fixed/azimuthing: |
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Azimuthing / Rolls Royce / UUC 505 | |
Motors per thruster: |
no. |
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1 | |
Make/type motors: |
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ABB Sami MegaStar | |
Total HP per thrusters |
bhp |
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7,478 (5,500 Kw) | |
Propeller type (fixed/variable blade): |
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|
Fixed pitch, variable speed | |
Nozzled: |
yes/no |
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Yes | |
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A.3.3 Dynamic Positioning |
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Make |
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Kongsberg | |
Model |
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|
Kongsberg K-POS DP32 | |
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Kongsberg K-POS DP12 Class 3 backup | |
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Designed according to ABS DPS-3 | |
Full DP or Mooring Assist: |
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Full DP | |
Position Reference: |
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1 x DGPS Seatex DPS-132 | |
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1 x DGPS Seatex DPS 200, | |
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2 x Simrad HiPAP 501 Hydroacoustic Systems | |
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A.4 OPERATIONAL CAPABILITIES |
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Maximum designed water depth capability: |
m |
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3,048 10,000 ft | |
Outfitted max. water depth capability: |
m |
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3,048 10.000 ft | |
Drilling depth capability (rated): |
m ft |
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11,429 37,500 ft | |
Transit speed towed (historical avg.): |
kts |
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N/A | |
Transit speed self propelled |
kts |
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12.0 knots at transit draft |
A.5 VARIABLE LOADING (VL) |
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Transit VL: |
mt |
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16,500 |
Drilling VL: |
mt |
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20,000 |
Survival VL: |
mt |
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20,000 |
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A.6 ENVIRONMENTAL LIMITS |
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Drilling |
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Air gap (below lower deck) |
m |
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N/A |
Max. wave height |
m |
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6.7 |
Max. wave period |
sec |
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7-10 |
Max. wind velocity (1 min mean) |
kts |
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52 |
Max. current velocity |
kts |
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3.5 |
Max. heave (double amplitude) |
m |
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6 |
Max. pitch (double amplitude) |
degrees |
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4.4º |
Max. roll (double amplitude) |
degrees |
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6º |
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Design Criteria |
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Air gap (below lower deck) |
m |
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N/A |
Max. wave height |
m |
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14.4 |
Max. Wave crest height |
m |
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22 |
Max. wave period |
sec |
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17 |
Max. wind velocity |
m/sec |
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51.4 for 1 min. , 61.7 for 3 sec. |
Max. current velocity |
kts |
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1.92 @ surface and 0 @ bottom |
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A.7 MOORING SYSTEM |
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A.7.1 Anchor Winches |
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Quantity |
no. |
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1 |
Make/model |
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Rolls-Royce |
Model |
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Type CU 107 U3 H |
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55.4 Tons @ 9m/min |
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Max Pull 83.2 tonnes |
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Brake holding load 365.1 tonnes |
Type (electric/hydraulic/diesel) |
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Hydraulic |
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A.7.2 Fairleads |
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Quantity: |
no. |
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N/A |
Make: |
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N/A |
Free rotating range: |
degrees |
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N/A |
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A.7.3 Anchors |
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A.7.3.1 Anchors Primary |
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Quantity: |
no. |
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1 |
Type: |
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Stockless type |
Weight: |
lt |
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14.1 tons |
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A.7.3.2 Anchors - Spare |
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Quantity: |
no. |
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0 |
Make: |
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N/A |
Type: |
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N/A |
Weight: |
lt |
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N/A |
A.7.4 Anchor Lines |
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Wire |
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Quantity: (installed/spare): |
no. |
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N/A |
Make/type: |
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N/A |
Specification: |
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N/A |
Diameter: |
in |
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N/A |
Weight per unit length: |
lbs/ft |
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N/A |
Useful length (nominal): |
ft |
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N/A |
Classification: |
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N/A |
Breaking strength: |
lt |
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N/A |
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Chain |
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Quantity: (installed/spare): |
no. |
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Installed |
Make/type: |
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DAI HAN ANCHOR CHAIN MFG.CO.LTD |
Diameter: |
mm |
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107 4 ¼ |
Shot length |
m |
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12x27.5MTRS / 1x17.5 MTRS / 1x3.8MTRS |
Shot Number |
no. |
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AS ABOVE |
Useful length (Class Requirement) |
m ft |
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330 |
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A.7.5 Anchors Line Running & Retrieval System |
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Primary type (pennant-buoy or chaser): |
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N/A |
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A.7.5.1 Pennant Lines |
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Quantity: |
no. |
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N/A |
Make: |
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N/A |
Type: |
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N/A |
Length: |
ft |
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N/A |
Diameter: |
m |
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N/A |
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A.7.5.2 Anchor Buoys |
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Quantity |
no. |
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N/A |
Volume each: |
m3 |
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N/A |
Type: |
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N/A |
Foam filled: |
yes/no |
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N/A |
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A.7.5.3 Smit Bracket |
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Location |
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Focsle |
Quantity |
no. |
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1 |
Make: |
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TANKTECH COMPANY LTD |
Type: |
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KETA-45F 200TON |
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A.7.6 Emergency Towing Gear |
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Location |
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Poopdeck |
Type |
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KET-40A |
Hook-up system |
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Fully-rigged Fairlead & Strongpoint |
Rating: |
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200 T |
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A.7.7 Mooring Winches |
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Quantity |
no. |
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9 |
Locations |
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Focsle, midships & poopdeck | |
Type |
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Wire 200m x 32mm plus 11m nylon rope tail | |
Minimum Breaking Load of wires |
mT |
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65 | |
Power Rating |
mT x m/min |
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20 x 15 | |
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A.7.8 Mooring Lines |
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Quantity |
no. |
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8 | |
Locations (port/stbd/both): |
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Both | |
Type |
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Polypropolene 8-strand Flexply | |
Size: |
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220m coils x 180mm | |
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A.7.9 Supplyboat Mooring Lines |
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(As above) | |
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Quantity |
no. |
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N/A | |
Locations (port/stbd/both): |
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N/A | |
Type; |
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N/A | |
Size: |
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N/A | |
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A.8 MARINE LOADING HOSES |
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Locations of loading manifolds (port/stbd/both): |
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Both | |
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A.8.1 Potable Water Hose |
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Quantity: |
no. |
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1 | |
Size: |
in |
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4 x 130 single-length | |
Make/type: |
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Titan / SW 333 150 PSI Swaged nipples | |
Color coding: |
yes/no |
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Blue | |
Make/type connection: |
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4 Male Weco Hammerlock & cover | |
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A.8.2 Drilling Water Hose |
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Quantity: |
no. |
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2 | |
Size: |
in |
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4 x 130 single-length | |
Make/type: |
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Powerflex Oil Transfer 150 PSI Swaged nipples | |
Color coding: |
yes/no |
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Yes | |
Make/type connection: |
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4 Male Weco Hammerlock | |
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A.8.3 Fuel Oil Hose |
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Quantity: |
no. |
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2 | |
Size: |
in |
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4 x 130 single-length swaged nipples | |
Make/type: |
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Goodall N2492 Petral 2000 Petroleum 200 PSI | |
Color coding: |
yes/no |
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Yes | |
Make/type connection: |
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4 Male Weco Hammerlock | |
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with 4 ball valve close coupled | |
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A.8.4 Mud Hose |
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Quantity: |
no. |
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2 | |
Size: |
in |
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4 x 130 single-length | |
Make/type: |
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Powerflex Oil Transfer 150 PSI Swaged nipples | |
Color coding: |
yes/no |
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Yes | |
Make/type connection: |
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4 Male Weco Hammerlock | |
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with 4 ball valve close coupled | |
A.8.5 Cement Hose |
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Quantity: |
no. |
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2 |
Size: |
in |
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5 x 130 single-length |
Make/type: |
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Soft Wall 6 x 150 ft long Swaged nipples |
Color coding: |
yes/no |
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Yes |
Make/type connection: |
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5 Male Weco Hammerlock & cover |
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A.8.6 Barite/Bentonite Hose |
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Quantity: |
no. |
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2 |
Size: |
in |
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5 x 130 single-length |
Make/type: |
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Soft Wall 6 x 150 ft long Swaged nipples |
Color coding: |
yes/no |
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Yes |
Make/type connection: |
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5 Male Weco Hammerlock & cover |
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A.8.7 Base Oil Hose |
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Quantity: |
no. |
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2 |
Size: |
in |
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4 x 130 single-length |
Make/type: |
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Powerflex Oil Transfer 150 PSI Swaged nipples |
Color coding: |
yes/no |
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Yes |
Make/type connection: |
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4 Male Weco Hammerlock |
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with 4 ball valve close coupled |
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A.8.8 Brine Hose |
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Quantity: |
no. |
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2 |
Size: |
in |
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4 x 130 single-length |
Make/type: |
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Powerflex Oil Transfer 150 PSI Swaged nipples |
Color coding: |
yes/no |
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Yes |
Make/type connection: |
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4 Male Weco Hammerlock |
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A.9 CRANES, HOISTS & MATERIALS HANDLING |
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A.9.1 Cranes, Revolving, Main |
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Quantity: |
no. |
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4 |
Specification (API, etc): |
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API |
Make: |
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NOV |
Type: |
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Knuckle-Boom Electro-Hydraulic Crane |
Location (stbd,port,aft, frwd): |
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Stbd aft, Stbd Fwd, Port Aft, Port Fwd |
Boom length: |
m |
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42.3 |
Hook reach below main deck |
m |
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ABLE TO REACH MINIMUM OF 19MTRS |
Load/radius |
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85 mT @ 18m |
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34 mT @ 39m |
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17 mT @ 42m |
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Able to lift 85 mton x-mas tree between moon- pool area and supply boat |
Hoisting Speed |
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0-10 m/min |
Maximum Luffing Speed |
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100 secs from max to min radius |
Maximum Load Slewing Speed |
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0.5 to 1.0 RPM |
Drum Capacity for Hoisting Height |
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240m below slewing bearing on single part |
Hook load indicator automatically corrected for boom angle: |
yes/no |
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Yes |
Alarm (audible, visual, both): |
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Audible |
Automatic brake: |
yes/no |
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Yes |
Safety latch on hooks: |
yes/no |
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Yes |
Crown saver (limit switch): |
yes/no |
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Yes |
Boom illumination: |
yes/no |
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Yes |
Boom CCTV Camera for Operator |
yes/no |
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No |
Riser & Pipe Handling Equipment |
yes/no |
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Yes 2 Riser handling Yokes & 1 pipe gripper |
Baskets for personnel transfer |
no. |
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1 |
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A.9.2 Helideck Crane |
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Quantity: |
no. |
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1 |
Specification (API, etc): |
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API |
Make: |
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Hochang |
Type: |
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Electro-Hydraulic |
Location (stbd,port,aft, frwd): |
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Helideck aft |
Boom length: |
m |
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20 |
Capacity |
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10 mT SWL |
Working Radius |
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4.5m to 20m |
Hoisting Speed |
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10m/min @ SWL 20m/min @ no load |
Luffing Time |
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60 seconds |
Slewing Speed |
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1.0 RPM |
Hook load indicator automatically corrected for boom angle: |
yes/no |
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No |
Alarm (audible, visual, both): |
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Audible |
Automatic brake: |
yes/no |
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Yes |
Safety latch on hooks: |
yes/no |
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Yes |
Crown saver (limit switch): |
yes/no |
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Yes |
Boom illumination: |
yes/no |
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Yes |
Baskets for personnel transfer: |
no. |
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1 |
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A.9.3 Forklifts |
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Quantity: |
no. |
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2 |
Make/type: |
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Doosan |
Rated capacity: |
lt |
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3 tons |
Explosion proof: |
yes/no |
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No |
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A.9.4 Monorail Overhead Cranes |
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Quantity: |
no. |
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Make: |
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Type: |
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Related Capacity: |
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Location: |
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Electric Chain Hoist |
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Quantity: |
no. |
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3 |
Make: |
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LK Hoist Co. Ltd |
Type: |
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3 phase induction motor |
Power: |
KW LT |
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0.4 |
Location: |
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STBD/PORT/Centr/Engine room |
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Motor for the electric chain hoist |
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Quantity: |
no. |
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Make: |
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3 |
Type: |
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LK Hoist Co. Ltd |
Power: |
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3 phase induction motor |
Location: |
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2/0.5 |
Electric Chain Hoist |
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STBD/PORT/Centr/Engine room |
Quantity: |
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Make: |
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3 |
Type: |
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LK Hoist Co. Ltd |
Rated capacity: |
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LTD-2W |
Location: |
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2 Ton |
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STBD/PORT/Centr/Engine room |
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A.9.5 BOP Handling System |
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Make |
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NOV |
Type |
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BOP Gantry Crane |
Rated capacity: |
mt |
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2 x main hoists 200 mt each |
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2 x aux hoists of 35 mt each |
Make |
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NOV |
Type |
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BOP Trolley |
Rated capacity: |
mt |
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420 |
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Make |
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NOV |
Type |
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BOP Bulkhead Guiding |
Rated capacity: |
mt |
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400 |
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Make: |
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NOV |
Type: |
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Base Plate 200 mT / X-mas Tree Trolley |
Quantity: |
no |
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1 Each |
Rated capacity: |
mt |
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200 with 2 each 120 mT X-mas Tree skids |
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A.9.6 Air Hoists/Derrick Winches |
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A.9.6.1 Rig Floor Winches (Non man-riding) |
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Quantity: |
no. |
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4 |
Make: |
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NOV |
Type: |
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Hydraulic |
Rated capacity: |
mt |
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5 |
Wire diameter: |
mm |
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19 |
Wire Length |
m |
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120 |
Automatic brakes: |
yes/no |
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Yes |
Overload protection: |
yes/no |
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Yes |
Automatic spooling: |
yes/no |
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Yes |
A.9.6.2 Monkey Board Work Winch |
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Quantity: |
no. |
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2 |
Make: |
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NOV |
Type: |
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Hydraulic |
Rated capacity: |
lb |
|
2200 |
Wire diameter: |
in |
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¼ |
Wire Length |
m |
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40 |
Automatic brakes: |
yes/no |
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Yes |
Overload protection: |
yes/no |
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N/A |
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A.9.6.3 Rig Floor Man-Riding Winch |
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Quantity: |
no. |
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3 |
Make: |
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NOV |
Type: |
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Hydraulic |
Rated capacity: |
kg |
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150 |
Wire diameter: |
mm |
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10 |
Wire Length |
m |
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140 |
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Non-twist wire: |
yes/no |
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Yes |
Automatic brakes: |
yes/no |
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Yes |
Overload protection: |
yes/no |
|
Yes |
Automatic spooling: |
yes/no |
|
Yes |
Certified for man-riding: |
yes/no |
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Yes |
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A.9.6.4 Utility Winch (Moonpool) |
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Quantity: |
no. |
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4 |
Make: |
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NOV |
Type: |
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Hydraulic |
Rated capacity: |
mt |
|
5 |
Wire diameter: |
mm |
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19 |
Wire Length |
m |
|
120 |
Automatic brakes: |
yes/no |
|
Yes |
Overload protection: |
yes/no |
|
Yes |
Automatic spooling: |
yes/no |
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Yes |
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A.9.6.5 Moonpool Man-Riding Winch |
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Quantity: |
no. |
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3 |
Make: |
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NOV |
Type: |
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Hydraulic |
Rated capacity: |
lt |
|
150 kg |
Wire diameter: |
in |
|
10mm |
Non-twist wire: |
yes/no |
|
Yes |
Automatic brakes: |
yes/no |
|
Yes |
Overload protection: |
yes/no |
|
Yes |
Automatic spooling: |
yes/no |
|
Yes |
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A.10 HELICOPTER LANDING DECK |
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Location: |
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Forward (above accommodation) |
Type |
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Aluminium |
Dimensions: |
m x m |
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Octagonal 27.2 x 27.2 |
Perimeter safety net: |
yes/no |
|
Yes |
Load capacity: |
mt |
|
21.3 |
Designed for helicopter type: |
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Chinook (exceeds S-92 req.) |
Tie down points: |
yes/no |
|
Yes |
Covered by foam fire system: |
yes/no |
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Yes 3 fire monitors | |
Helideck lighting to aviation specification as required by country of operation: |
yes/no |
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CAP 437 compliant | |
Helicopter Beacon Transmitter |
yes/no |
|
Yes | |
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A.10.1 Helicopter Refueling System |
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| |
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Specification |
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|
CAP-437 | |
Fuel storage capacity: |
Lt |
|
3 Transportable tanks of 2,900lt capacity each | |
Jettisonable: |
yes/no |
|
Yes | |
Fuel transport containers: |
qty |
|
0 | |
Volume (ea): |
Lt |
|
NA | |
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| |
Covered by foam fire system: |
yes/no |
|
No | |
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A.11 AUXILIARY EQUIPMENT |
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| |
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A.11.1 Water Distillation |
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| |
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| |
Quantity: |
no. |
|
3 | |
Make/type: |
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SASAKURA / EX-40E | |
Capacity (each/total): |
T/day |
|
40T/120T | |
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A.11.2 Boilers |
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| |
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| |
Quantity: |
no. |
|
2 | |
Make/type: |
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Kangrim Industries Co. LTD | |
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MB0101DR02 | |
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Working Press 15.7 Bar | |
Capacity (total system): |
lbs/hr |
|
10,000 kg/hr (1) | |
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A.11.3 Air Conditioning |
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| |
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| |
Quantity: |
no. |
|
2 (accomodations) | |
Make/type: |
|
|
Hi-Air Korea Condensing Units | |
Capacity (total system): |
|
|
Total 1,216 kW | |
|
|
|
| |
A.11.4 Electric Welding Sets |
|
|
| |
|
|
|
| |
Quantity: |
no. |
|
2 | |
Current capacity: |
amp |
|
400 | |
Make/model: |
|
|
UNITOR / UWI-400 | |
Type: |
fixed/portable |
|
Fixed | |
|
|
|
| |
A.11.5 High Pressure Cleaner |
|
|
| |
|
|
|
| |
Quantity: |
no. |
|
1 | |
Make/type: |
|
|
UNITOR TYPE KEW | |
Electric/pneumatic/diesel: |
|
|
Electric | |
Max delivered pressure: |
psi |
|
2,240 | |
B. GENERAL RIG SPECIFICATIONS |
|
|
|
|
|
|
|
B.1 DERRICK AND SUBSTRUCTURE |
|
|
|
|
|
|
|
Make |
|
|
NOV |
Type |
|
|
Dual Dynamic bottle-neck Type API Spec 4 /RP4E, one drawworks and one topdrive only, in main activity centre |
Rated for wind speed |
|
|
|
With full set back: |
kts |
|
60 (1,200mt set back) |
With no set back: |
kts |
|
100 ( 900mt set back) |
Free Internal Lifting Height: |
ft |
|
161 ft 49m |
Distance between Well centers |
ft |
|
40 |
Dimensions of base: |
ft x ft |
|
60 x 80 |
Water Table Dimensions Main Well : |
ft x ft |
|
20 x 20 |
Water Table Dimensions Aux Well : |
ft x ft |
|
20 x 20 |
Gross nominal capacity: |
lb |
|
2,000,000 Main Well and 1,000,000 Aux. simultaneously |
Maximum number of lines Main Well: |
no. |
|
14 |
Maximum number of lines AUX Well: |
no. |
|
N / A |
Personal Elevator |
yes/no |
|
Yes |
Ladders with safety cages and rests: |
yes/no |
|
Yes |
Platform for crown sheave access: |
yes/no |
|
Yes |
Counter balance, system for rig tongs and pipe spinning tong: |
yes/no |
|
N/A |
Lighting system explosion proof: |
yes/no |
|
Yes |
|
|
|
|
B.1.2 Racking Platform |
|
|
|
|
|
|
|
Make/type: |
|
|
NOV |
Racking platform capacity of 6 5/8 DP: |
ft |
|
32,130 (252 stds) + 14,025 (110 stds x 5 7/8) |
or |
|
|
|
Racking platform capacity of 5 7/8 or 5 ½ DP |
ft |
|
46,155 (362 stds of 127.5) |
and |
|
|
|
Racking platform capacity of 9 ½ DC: |
no. |
|
6 stds (720) |
and |
|
|
|
Racking platform capacity of 8 1/4 DC |
no. |
|
12 stds (1,440) |
and |
|
|
|
Racking platform capacity of 6 ¾ DC: |
no. |
|
6 stds (720) |
and |
|
|
|
Racking platform capacity of 4 ¾ DC: |
no. |
|
11 stds (1,320) |
and |
|
|
|
Racking platform capacity of casing: (± 127.5)no. |
|
|
80 x 13 3/8 (10,200)or 105 x 9 5/8 (13,388) or 105 x 7 (13,388) |
|
|
|
|
B.1.3 Racking Arm |
|
|
|
|
|
|
|
Make |
|
|
NOV |
Type |
|
|
2 each NOV - HydraRacker HR IV 3 ½, 4 ¾, 5, 5 7/8 , 6 5/8, 6 ¾, 7, 7 5/8, 8 ¼, 9 5/8, 10 ¾, 13 3/8, 14, 20 |
|
|
|
|
B.1.4 Maintenance Work Basket |
|
|
|
|
|
|
|
Make |
|
|
Hydralift 2 each in derrick, 2 each in moonpool |
Type |
|
|
STB-300-90C 120-10 |
Adjustable from/to height above rotary: |
m/m |
|
0 to 20 |
|
|
|
|
B.1.5 Substructure |
|
|
|
|
|
|
|
Make/type: |
|
|
SHI |
Height (above main deck): |
m |
|
18 |
Length: |
m ft |
|
29.54 |
Width: |
m |
|
29.49 |
Setback capacity: |
kips |
|
2640 (2 x 770 + 1,100 casing ) |
Simultaneous setback + hookload capacity |
kips |
|
2,640 + 2,000 + 1,000 |
Clear height below R/table beams (x-mas trees handling): |
|
8,2 m clear height above xmas tree trolley | |
|
|
|
|
B.1.6 Weather Proofing |
|
|
|
|
|
|
|
Rig floor windbreaks height: |
ft |
|
16 ½ |
Derrickman windbreaks height: |
ft |
|
30 level 108 to 138 |
|
|
|
|
B.1.7 Derrick TV Camera System |
|
|
|
|
|
|
|
Camera located at: |
|
|
Monkey board, crown, stabbing board, drill floor, shakers, moonpool, on-and offline pipe handling system, Drawworks, Flow divider |
Make/type: |
|
|
Hernis Scan Systems AS |
Zoom/Pan/Tilt-function: |
yes/no |
|
Yes |
Monitor located at: |
|
|
Doghouse, toolpusher office, bridge, company man office, ET workshop and ECR |
|
|
|
|
B.2 DRAWWORKS AND ASSOCIATED EQUIPMENT |
|
| |
|
|
|
|
B.2.1 Drawworks |
|
|
|
|
|
|
|
Make |
|
|
NOV |
Type |
|
|
SSGD 1,000-5,750 |
Motors make/type: |
|
|
Baylor CM 628-TUT/ AC motor |
Quantity: |
no. |
|
5 |
Maximun input power continuous: |
hp |
|
5,750 |
Maximun output power intermittent: |
hp |
|
5,750 |
Drum type: |
|
|
Lebus grooved |
Drum diameter: |
in |
|
55 |
Drum Lenght |
in |
|
82 |
Wire diameter: |
in |
|
2 |
Maximum line pull 14 lines: |
lb |
|
2,000,000 |
Maximum line pull 12 lines: |
lb |
|
1,738,000 |
|
|
|
|
Spinning cathead type: |
|
|
None |
Breakout cathead type: |
|
|
NOV / Model CAR P15-2 Hydraulic cathead dual. |
Crown block safety device make/type: |
|
|
NOV-Hi-Tec integrated control system |
Independent fresh water cooling system for drawworks and electric brake: |
yes/no |
|
Drawworks lube oil cooling system and hydraulic brake cooling system. |
B.2.2 Auxiliary Brake |
|
|
|
|
|
|
|
Make: |
|
|
N/A |
Model: |
|
|
N/A |
Independent back-up system type: |
|
|
Fail Safe spring applied disk brakes for parking and emergency |
|
|
|
|
B.2.3 Sandline |
|
|
|
|
|
|
|
Make: |
|
|
N/A |
Length capacity: |
ft |
|
N/A |
Line size/type: |
in |
|
N/A |
Breaking strength: |
lt |
|
N/A |
Safe working load: |
lt |
|
N/A |
|
|
|
|
B.2.4 Wireline |
|
|
|
|
|
|
|
Make: |
|
|
See H.5.2 |
Length capacity: |
ft |
|
N/A |
Line size/type: |
in |
|
N/A |
|
|
|
|
B.2.5 Automatic Driller |
|
|
|
|
|
|
|
Make/type: |
|
|
Incorporated in HiTec WOB/ROP Mode |
|
|
|
|
B.3 DERRICK HOISTING EQUIPMENT |
|
|
|
|
|
|
|
B.3.1 Crown Block (CMC see data below) |
|
|
|
|
|
|
|
Make/type: |
|
|
NOV |
Rated capacity: |
kips |
|
2,000 |
No. of sheaves: |
no. |
|
6 on main sheave cluster + 2 on tandem fastline + 2 on tandem deadline |
Sheaves diameter: |
in |
|
72 |
Sheave grooved for line size: |
in |
|
2 |
|
|
|
|
B.3.2 Travel Block |
|
|
|
|
|
|
|
Make |
|
|
NOV / Integrated Travelling Block, Hook and Swivel with Top Drive. |
Type |
|
|
HTB 1,000 7 x 72- 2 |
Rated capacity: |
kips |
|
2,000 |
No. of sheaves: |
no. |
|
7 |
Sheaves diameter: |
in |
|
72 |
Sheave grooved for line size: |
in |
|
2 |
|
|
|
|
B.3.3 Hook |
|
|
|
|
|
|
|
Make/type: |
|
|
See B.3.2 |
Rated capacity: |
mt |
|
N/A |
Complete with spring assembly/hook locking device: |
yes/no |
|
N/A |
B.3.4 Swivel |
|
|
|
|
|
|
|
Make |
|
|
See B.4.4 |
Type |
|
|
|
Rated capacity: |
kips |
|
2,000 |
Test/working pressure: |
psi/psi |
|
7,500 |
Gooseneck and washpipe minimum ID>= 76mm: |
yes/no |
|
Yes 78mm |
Left hand pin connection size: |
in |
|
7 5/8 Reg (Rigth hand Top Drive) |
Access fitting for wireline entry on top of gooseneck: |
yes/no |
|
Yes |
|
|
|
|
B.3.5 Drilling Line |
|
|
|
|
|
|
|
Diameter: |
in |
|
2 |
Type: |
|
|
6x19 EIPS IWRC |
Length (original): |
ft |
|
15,000 |
Support frame for drum: |
yes/no |
|
Yes |
Drilling line drum power driven: |
yes/no |
|
Yes |
Spare reel drilling line: |
yes/no |
|
Yes, 15,000 |
Location (rig, shore, etc.): |
|
|
Shore |
|
|
|
|
B.3.6 Anchor Dead Line |
|
|
|
|
|
|
|
Make |
|
|
NOV |
Type |
|
|
FRH 200 CHR, Rotary Slip Deadline |
Weight sensor: |
yes/no |
|
Yes |
|
|
|
|
B.3.7 Crown Mounted Motion Compensator |
|
|
|
|
|
|
|
Make |
|
|
NOV |
Type |
|
|
CMC (passive + active mode) |
Stroke: |
ft |
|
25 |
Capacity - compensated: |
kips |
|
1,000 |
Capacity locked : |
kips |
|
2,000 |
|
|
|
|
B.3.8 Block Guidance System |
|
|
|
|
|
|
|
Make |
|
|
NOV |
Type |
|
|
Complete set of guide tracks to accommodate the retractable HPS10002E-AC-KT |
|
|
|
|
B.3.9 Retraction System for Traveling Block |
|
|
|
|
|
|
|
Make |
|
|
NOV |
Type |
|
|
Block Retract system |
|
|
|
|
B.4 ROTATING SYSTEM |
|
|
|
|
|
|
|
Rotating Mousehole |
|
|
N/A |
|
|
|
|
B.4.1 Rotary Table |
|
|
|
|
|
|
|
Make |
|
|
NOV-Varco |
Type |
|
|
BJ-RST60.5 |
Maximum opening: |
in |
|
60 ½ |
Rated capacity: |
kips |
|
2,000 |
Static load capacity: |
kips |
|
2,000 |
Rotating load capacity: |
kips @ rpm |
|
1,500 @ 15 rpm max. | |
Two speed gearbox: |
yes/no |
|
No | |
Emergency chain drive: |
yes/no |
|
No | |
Driven by an independent electric motor: |
yes/no |
|
No/Hydraulic drive | |
Electric motor type/make: |
|
|
| |
Maximum continuous torque: |
ft lbs |
|
45,000 | |
Drip pan/mud collection system: |
yes/no |
|
Yes | |
|
|
|
| |
B.4.2 Master Bushings |
|
|
| |
|
|
|
| |
Make/type: |
|
|
NOV-Varco | |
Type |
|
|
MPCH | |
Insert bowls #3, #2, #1: |
no. |
|
1 set each | |
|
|
|
| |
B.4.3 Kelly Bushing |
|
|
| |
|
|
|
| |
Make/type: |
|
|
N/A | |
Lock down assembly: |
yes/no |
|
N/A | |
|
|
|
| |
B.4.4 Top Drive |
|
|
| |
|
|
|
| |
Make |
|
|
NOV | |
Model |
|
|
HPS10002E-AC-KT | |
Type (electric/hydraulic): |
|
|
Electric AC | |
Rated capacity: |
st |
|
1,000 | |
Test/working pressure: |
psi/psi |
|
7,500 | |
If driven by electric motor |
|
|
| |
Make/type: |
|
|
2 x GEB 20 B2 AC | |
Output power: |
hp |
|
1,150 | |
Maximum continuous torque: |
ft lbs |
|
78,000 | |
Two speed gearbox: |
yes/no |
|
No | |
Maximum rotary speed: |
rpm |
|
280 | |
Remote operated kelly cock: |
yes/no |
|
Yes | |
Cooling system type: |
|
|
Local Blower | |
|
|
|
| |
B.4.4.1 Top Drive Makeup/Breakout System |
|
|
| |
|
|
|
| |
Make: |
|
|
NOV | |
Model: |
|
|
| |
Type: |
|
|
Pipe Handler | |
Max. breakout torque that can be applied by system: |
ft-lbs |
|
115,000 | |
C. POWER SUPPLY SYSTEMS |
|
|
|
|
|
|
|
C.1 RIG POWER PLANT |
|
|
|
|
|
|
|
C.1.1 Diesel Engines |
|
|
|
|
|
|
|
Quantity: |
no. |
|
6 |
Make |
|
|
Wartsila |
Type |
|
|
16V32/40 |
Maximum continuous power: |
kw |
|
7,290 |
At rotation speed of: |
rpm |
|
720 |
Equipped with spark arrestors: |
yes/no |
|
Yes |
Mufflers installed: |
yes/no |
|
Yes |
|
|
|
|
C.1.2 DC Generator |
|
|
|
|
|
|
|
Quantity: |
no. |
|
0 |
Make/type: |
|
|
N/A |
Continuous power: |
kw |
|
N/A |
At rotation speed of: |
rpm |
|
N/A |
Output volts: |
volts |
|
N/A |
|
|
|
|
C.1.3 AC Generator |
|
|
|
|
|
|
|
Quantity: |
no. |
|
6 |
Make |
|
|
ABB |
Type |
|
|
AMG 0900XU10 |
Continuous power: |
kva |
|
8,750 @ 0.8 pf |
At rotation speed of: |
rpm |
|
720 |
Output volts: |
volts |
|
11,000 |
|
|
|
|
C.1.4 VFD System |
|
|
|
|
|
|
|
Number of Diode Supply units: |
no. |
|
4 (Total 8 Units, 4 in each SWBD) |
Make/type: |
|
|
ABB/ ACS 800-507LC-3820-7 |
Rating : |
kva |
|
3824 |
Supply volts: |
volts |
|
690 |
No. phase |
|
|
3 phase |
No. of pulses |
|
|
12 pulse |
|
|
|
|
Number of Top drives & Mud Pumps VFD: |
no. |
|
12 |
Make/type: |
|
|
ABB/ ACS800LC-1370-7 |
Nominal Power: |
kva |
|
1370 |
Output volts: |
volts |
|
690 |
|
|
|
|
Number of Drawworks VFD: |
no. |
|
10 |
Make/type: |
|
|
ABB/ ACS800LC-1590-7 |
Nominal Power: |
kva |
|
1590 |
Output volts: |
volts |
|
690 VAC |
|
|
|
|
Number of Dynamic Braking Unit: |
no. |
|
8 |
Make/type: |
|
|
ABB/ ACS800-607LC-1300-7 |
Braking Power: |
kw |
|
1200 KW (each) |
Input volts (Max): |
volts |
|
1200 Vdc. |
|
|
|
|
Quantity: |
no. |
|
2 (Drilling) |
Make/type: |
|
|
ABB / RESIBLOC, Dry type tranformer |
Continuous power (each): |
kva |
|
7,200 |
Output volts: |
volts |
|
725 |
Frequency: |
Hz |
|
60 |
|
|
|
|
Quantity: |
no. |
|
6 (Thruster Drive) |
Make/type: |
|
|
ABB / RESIBLOC, Dry type tranformer |
Continuous power (each): |
kva |
|
6,500 |
Output volts: |
volts |
|
1672 |
Frequency: |
Hz |
|
60 |
|
|
|
|
Quantity: |
no. |
|
2 (Thruster Aux 2&3) |
Make/type: |
|
|
ABB / RESIBLOC, Dry type tranformer |
Continuous power (each): |
kva |
|
2,000 |
Output volts: |
volts |
|
450 |
Frequency: |
Hz |
|
60 |
Quantity: |
no. |
|
3 (AFT E/R TRANSFORMERS) |
Make/type: |
|
|
ABB / RESIBLOC, Dry type tranformer |
Continuous power (each): |
kva |
|
2,000 |
Output volts: |
volts |
|
450 |
Frequency: |
Hz |
|
60 |
|
|
|
|
Quantity: |
no. |
|
2 (TOP SIDE) |
Make/type: |
|
|
SANIL |
Continuous power (each): |
kva |
|
2,700 |
Output volts: |
volts |
|
450 |
Frequency: |
Hz |
|
60 |
|
|
|
|
Quantity: |
no. |
|
1 (THRUSTER 1 AUX) |
Make/type: |
|
|
ABB / RESIBLOC, Dry type tranformer |
Continuous power (each): |
kva |
|
4,000 |
Output volts: |
volts |
|
450 |
Frequency: |
Hz |
|
60 |
|
|
|
|
Quantity: |
no. |
|
6 (THRUSTER AUX PANEL) |
Make/type: |
|
|
ABB |
Continuous power (each): |
kva |
|
25 |
Output volts: |
volts |
|
230 |
Frequency: |
Hz |
|
60 |
|
|
|
|
Quantity: |
no. |
|
4 (FWD 220) |
Make/type: |
|
|
SANIL |
Continuous power (each): |
kva |
|
200 |
Output volts: |
volts |
|
230 |
Frequency: |
Hz |
|
60 |
|
|
|
|
Quantity: |
no. |
|
3 (Aft Machinery) |
Make/type: |
|
|
SANIL |
Continuous power (each): |
kva |
|
125 |
Output volts: |
volts |
|
230 |
Frequency: |
Hz |
|
60 |
|
|
|
|
Quantity: |
no. |
|
2 (Emergency) |
Make/type: |
|
|
SANIL |
Continuous power (each): |
kva |
|
250 |
Output volts: |
volts |
|
230 |
Frequency: |
Hz |
|
60 |
C.1.6 Emergency Shutdown |
|
|
| |
|
|
|
| |
Emergency shutdown switches for the complete power system (AC & DC), located at the following points: |
|
|
Drilling Control Station, Emergency HQ Room and Aft CO2 room, plus through Vessel management system on bridge and ECR | |
|
|
|
| |
C.1.7 Auxiliary Power Supply |
|
|
| |
|
|
|
| |
Power supply for a mud logging unit: |
yes/no |
|
Yes | |
Power supply available |
|
|
| |
Output volts: |
volts |
|
440 | |
Frequency: |
Hz |
|
60 | |
Current: |
amps |
|
100 | |
Phase: |
single/three |
|
Three | |
|
|
|
| |
C.1.8 Compressed Air System |
|
|
| |
|
|
|
| |
Air Compressors - High Pressure: |
|
|
| |
Quantity: |
no. |
|
3 | |
Make: |
|
|
Hamworthy | |
Model: |
|
|
(4SW80) | |
Rated capacity: |
m3/hr |
|
120 (each) | |
Working press: |
Bar |
|
207 (Normal WP) | |
Prime mover (electric/diesel): |
|
|
Electric | |
Continuous power: |
kw |
|
43 | |
Air dryers: |
|
|
Yes | |
Quantity: |
no. |
|
2 | |
Make/type: |
|
|
Twin Tower / Hamworthy | |
Rated capacity: |
cfm |
|
75 | |
|
|
|
| |
Air Compressors Medium pressure |
|
|
| |
Quantity: |
no. |
|
4 | |
Make: |
|
|
Tamrotor | |
Model: |
|
|
M 132-10 EWNA | |
Rated capacity: |
cfm |
|
700 | |
Working press: |
psi |
|
130 | |
Prime mover (electric/diesel): |
|
|
Electric | |
Continuous power: |
hp |
|
137 | |
Air dryers: |
|
|
Yes | |
Quantity: |
no. |
|
2 | |
Make/type: |
|
|
Kyung Nam Dryer / KHDM-3000 | |
Rated capacity: |
cfm |
|
1,400 (each) | |
|
|
|
| |
Air Compressors Medium pressure |
|
|
| |
Quantity: |
no. |
|
3 (Starting air compressor) | |
Make: |
|
|
Jonghap-Tanabe | |
Model: |
|
|
H-73 | |
Rated capacity: |
m3/hr |
|
141 | |
Working press: |
bar |
|
30 | |
Prime mover (electric/diesel): |
|
|
Electric | |
Continuous power: |
kw |
|
37 | |
Air dryers: |
|
|
NO | |
Quantity: |
no. |
|
N/A | |
Make/type: |
|
|
N/A | |
C.2 EMERGENCY GENERATOR |
|
|
|
|
|
|
|
C.2.1 Engine |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make |
|
|
STX (CUMMINS MARINE) |
Type |
|
|
QSK60DMGE |
Maximum output: |
kw |
|
1,350 |
At rotation speed: |
rpm |
|
1,800 |
Starting methods (automatic, manual, air/hydraulic): |
|
|
Automatic, manual hydraulic/electric/battery |
|
|
|
|
C.2.2 AC Generator |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Stamford |
Type |
|
|
PM734E1 |
Maximum output: |
rpm |
|
1,800 |
At rotation speed: |
kw |
|
1,350 |
Output volts: |
volts |
|
450, 60Hz, 3-phase |
Capable of back-feeding power to main bus: |
yes/no |
|
No, but possible to feed FWD aux. Switchboard |
D. DRILLSTRING EQUIPMENT |
|
|
| ||
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|
|
| ||
D.1 TUBULARS |
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| ||
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|
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| ||
D.1.1 Kellys |
|
|
| ||
|
|
|
| ||
Quantity: |
no. |
|
N/A | ||
Nominal size OD: |
in |
|
N/A | ||
Shape type (hexagonal, square, triangular): |
|
|
N/A | ||
Total/working length: |
ft |
|
N/A | ||
Connection type: |
|
|
N/A | ||
API classification: |
|
|
N/A | ||
|
|
|
| ||
D.1.2 Kelly Saver Subs |
|
|
| ||
|
|
|
| ||
Quantity: |
no. |
|
N/A | ||
Nominal kelly size: |
in |
|
N/A | ||
Connection type: |
|
|
N/A | ||
API classification: |
|
|
N/A | ||
Protector: |
yes/no |
|
N/A | ||
|
|
|
| ||
D.1.3 Drill Pipe |
|
|
| ||
|
|
|
| ||
Drill pipe OD: (Landing String) |
in |
|
6 5/8 | ||
Grade: |
|
|
V-150 | ||
Total length: |
ft |
|
10,000 | ||
Range: |
|
|
Range 3 | ||
Weight: |
ppf |
|
50.4 (61.6 adj) | ||
Internally plastic coated: |
yes |
|
Yes TK34XT | ||
Tool joint OD/ID: |
in/in |
|
8.688 x 3.5 | ||
Tool joint pin length (original): |
in |
|
16 | ||
Tapered shoulder tool joints (box/pins): |
degree/degree |
|
18° / 18° | ||
Connection type: |
|
|
6 5/8 FH | ||
Type of hardfacing: |
|
|
None | ||
API classification: |
|
|
Premium (pipe is new) | ||
Thread protectors: |
yes/no |
|
Yes | ||
|
|
|
| ||
Drill pipe OD (Shear Joints) |
in |
|
6 5/8 (shear, joints, above casing hanger) | ||
Grade: |
|
|
S135 | ||
Total length: |
ft |
|
209 | ||
Range: |
|
|
Range 3 | ||
Weight: |
ppf |
|
34.00 | ||
Internally plastic coated: |
yes/no |
|
Yes TK34XT | ||
Tool joint OD/ID: |
in/in |
|
8.50 / 4 ¼ | ||
Tool joint pin length (original): |
in |
|
10 | ||
Tapered shoulder tool joints (box/pins): |
degree/degree |
|
18° / 18° | ||
Connection type: |
|
|
6 5/8 FH | ||
Type of hardfacing: |
|
|
TCSTi -(flush) | ||
API classification: |
|
|
Premium (pipe is new) | ||
Thread protectors: |
yes/no |
|
Yes | ||
Drill pipe OD: |
in |
|
5 7/8 | |
Grade: |
|
|
S135 | |
Total length: |
ft |
|
25,000 | |
Range: |
|
|
Range 3 | |
Weight: |
ppf |
|
26.30 | |
Internally plastic coated: |
yes/no |
|
Yes (TK34XT) | |
Tool joint OD/ID: |
in/in |
|
7 x 4 ½ | |
Tool joint pin length (original): |
in |
|
10 | |
Tapered shoulder tool joints (box/pins): |
degree/degree |
|
18° / 18° | |
Connection type: |
|
|
Turbotorque 585 | |
Type of hardfacing: |
|
|
TCSTi -(flush) | |
API classification: |
|
|
Premium (pipe is new) | |
Thread protectors: |
yes/no |
|
Yes | |
|
|
|
| |
Drill pipe OD: |
in |
|
5 | |
Grade: |
|
|
S-135 | |
Total length: |
ft |
|
10,000 | |
Range: |
|
|
Range 3 | |
Weight: |
lbs/ft |
|
19.50 | |
Internally plastic coated: |
yes/no |
|
Yes | |
Tool joint OD/ID: |
in/in |
|
6 5/8 / 3 ¼ | |
Tool joint pin length (original): |
in |
|
12 | |
Tapered shoulder tool joints (box/pins): |
degree/degree |
|
18°/18° | |
Connection type: |
|
|
GPDS50 | |
Type of hardfacing: |
|
|
TCSTi | |
API classification: |
|
|
Premium (pipe is new) | |
Thread protectors: |
yes/no |
|
Yes | |
|
|
|
| |
D.1.4 Drill Pipe Pup Joints |
|
|
| |
|
|
|
| |
6 5/8 |
|
|
| |
|
|
|
| |
Tool joint OD/ID: |
in/in |
|
8 ¾ x 4 | |
Grade: |
|
|
Drill collar material | |
Length: |
ft |
|
5,10,15,20,30 | |
Quantity: |
no. |
|
2 x (5,10,15,20,30) | |
Length: |
ft |
|
| |
Quantity: |
no. |
|
| |
Length: |
ft |
|
| |
Quantity: |
no. |
|
| |
Weight: |
lbs/ft |
|
50.41 | |
Connection type: |
|
|
6 5/8 FH | |
Internally plastic coated: |
yes/no |
|
Yes | |
Thread protectors: |
yes/no |
|
Yes | |
|
|
|
| |
5 7/8 |
|
|
| |
|
|
|
| |
Tool joint OD/ID: |
in/in |
|
7 x4 ½ | |
Grade: |
|
|
Drill collar material | |
Length: |
ft |
|
5,10,15, 20, 30 | |
Quantity: |
no. |
|
2 x (5,10,15,20,30) | |
Weight: |
lbs/ft |
|
26.340 | |
Connection type: |
|
|
Turbotorque 585 | |
Internally plastic coated: |
yes/no |
|
Yes | |
Thread protectors: |
yes/no |
|
Yes | |
5 |
|
|
|
|
|
|
|
Tool joint OD/ID: |
in/in |
|
6 5/8 / 3 ¼ |
Grade: |
|
|
Drill collar material |
Length: |
ft |
|
5, 10, 15, 20, 30 |
Quantity: |
no. |
|
2 of each |
|
|
|
|
Weight: |
lbs/ft |
|
19.50 |
Connection type: |
|
|
GPDS50 |
Internally plastic coated: |
yes/no |
|
Yes |
Thread protectors: |
yes/no |
|
Yes |
|
|
|
|
D.1.5 Drill Pipe Casing Protectors |
|
|
|
|
|
|
|
Initial stock: |
no. |
|
N/A |
Make/type: |
|
|
N/A |
OD: |
in |
|
N/A |
Installation tools (manual/hydraulic/none): |
|
|
N/A |
|
|
|
|
D.1.6 Heavy Weight Drill Pipe (e.g. Hevi-Wate) |
|
|
|
|
|
|
|
Quantity: |
no. |
|
40 |
Nominal size OD: |
in |
|
5 7/8 |
Weight: |
lbs/ft |
|
61 |
Range: |
|
|
2 |
Tool joint OD: |
in |
|
7 |
Tool joint ID: |
in |
|
4 |
Type of hardfacing: |
|
|
Smooth |
Internally plastic coated: |
yes/no |
|
No |
Connection type: |
|
|
Turbotorque 585 |
Thread protectors: |
yes/no |
|
Yes |
|
|
|
|
Quantity: |
no. |
|
40 |
Nominal size OD: |
in |
|
5 |
Weight: |
lbs/ft |
|
49.3 |
Range: |
|
|
2 |
Tool joint OD: |
in |
|
6 5/8 |
Tool joint ID: |
in |
|
3 |
Type of hardfacing: |
|
|
Smooth |
Internally plastic coated: |
yes/no |
|
No |
Connection type: |
|
|
NC-50 (4 ½ IF) |
Thread protectors: |
yes/no |
|
Yes |
|
|
|
|
D.1.7 Drill Collars |
|
|
|
|
|
|
|
Quantity: |
no. |
|
12 |
OD body: |
in |
|
9 ½ |
ID body: |
in |
|
3 |
Nominal length of each joint: |
ft |
|
31 |
Drill collar body (slick/spiral): |
|
|
Spiral |
Recess for zip elevator: |
yes/no |
|
Yes |
Recess for slips: |
yes/no |
|
Yes |
Stress relief pin groove: |
yes/no |
|
Yes |
Boreback on box: |
yes/no |
|
Yes |
Connection type: |
|
|
7 5/8 Reg |
Quantity: |
no. |
|
30 |
OD body: |
in |
|
8 ¼ |
ID body: |
in |
|
3 |
Nominal length of each joint: |
ft |
|
31 |
Drill collar body (slick/spiral): |
|
|
Spiral |
Recess for zip elevator: |
yes/no |
|
Yes |
Recess for slips: |
yes/no |
|
Yes |
Stress relief pin groove: |
yes/no |
|
Yes |
Boreback on box: |
yes/no |
|
Yes |
Connection type: |
|
|
6 5/8 Reg |
|
|
|
|
Quantity: |
no. |
|
30 |
OD body: |
in |
|
6 ¾ |
ID body: |
in |
|
2-13/16 |
Nominal length of each joint: |
ft |
|
31 |
Drill collar body (slick/spiral): |
|
|
Spiral |
Recess for zip elevator: |
yes/no |
|
Yes |
Recess for slips: |
yes/no |
|
Yes |
Stress relief pin groove: |
yes/no |
|
Yes |
Boreback on box: |
yes/no |
|
Yes |
Connection type: |
|
|
NC-50 (4 ½ IF) |
|
|
|
|
D1.8 Short Drill Collars |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
OD body: |
in |
|
N/A |
ID body: |
in |
|
N/A |
Nominal length of each joint: |
ft |
|
N/A |
Stress relief pin groove: |
yes/no |
|
N/A |
Boreback on box: |
yes/no |
|
N/A |
Connection type: |
|
|
N/A |
|
|
|
|
D.1.9 Non-Magnetic Drill Collars |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
OD body: |
in |
|
N/A |
ID body: |
in |
|
N/A |
Nominal length of each joint: |
ft |
|
N/A |
Drill collar body (slick/spiral): |
|
|
N/A |
Recess for zip elevator: |
yes/no |
|
N/A |
Recess for slips: |
yes/no |
|
N/A |
Stress relief pin groove: |
yes/no |
|
N/A |
Boreback on box: |
yes/no |
|
N/A |
Connection type: |
|
|
N/A |
|
|
|
|
D.1.10 Core Barrels |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make: |
|
|
N/A |
Model: |
|
|
N/A |
Size OD x ID: |
in x in |
|
N/A |
Length: |
ft |
|
N/A |
Top connection type: |
|
|
N/A |
Spiral stabilizing ribs: |
yes/no |
|
N/A |
Subs and handling tools: |
yes/no |
|
N/A |
D.1.11 Stabilizers |
|
|
|
|
|
|
|
Hole size: |
in |
|
N/A |
Quantity: |
no. |
|
N/A |
Make: |
|
|
N/A |
OD blades: |
in |
|
N/A |
Type |
blades |
|
N/A |
Type of blade hardfacing: |
|
|
N/A |
OD body or fishing neck: |
in |
|
N/A |
ID body: |
in |
|
N/A |
Connection type: |
|
|
N/A |
Float valve receptacle: |
yes/no |
|
N/A |
|
|
|
|
D.1.12 Roller Reamers |
|
|
|
|
|
|
|
Hole size: |
in |
|
N/A |
Quantity: |
no. |
|
N/A |
Make: |
|
|
N/A |
OD body: |
in |
|
N/A |
ID body: |
in |
|
N/A |
OD fishing neck: |
in |
|
N/A |
Cutters, supplied sets: |
no. |
|
N/A |
Cutters, type: |
|
|
N/A |
Connection, type: |
|
|
N/A |
|
|
|
|
D.1.13 Shock Absorbers (Damping Sub) |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make/type: |
|
|
N/A |
OD body: |
in |
|
N/A |
ID body: |
in |
|
N/A |
OD fishing neck: |
in |
|
N/A |
Connection type: |
|
|
N/A |
|
|
|
|
D.1.14 Drilling Jars |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make: |
|
|
N/A |
Type (mechanical/hydraulic;up/down): |
|
|
N/A |
OD body: |
in |
|
N/A |
Min. ID body: |
in |
|
N/A |
OD fishing neck: |
in |
|
N/A |
Stroke: |
in |
|
N/A |
Connection type: |
|
|
N/A |
|
|
|
|
D.1.15 Inside BOP Valve |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 |
Make: |
|
|
VAM-(Omsco) |
OD: |
in |
|
8 (ID-2-13/16) |
Min. drill pipe ID required: |
in |
|
(Check valve) |
Connection type: |
|
|
6 5/8 FH |
Working pressure rating: |
psi |
|
15,000 |
|
|
|
|
Quantity: |
no. |
|
2 |
Make: |
|
|
VAM-(Omsco) |
OD: |
in |
|
6 5/8 |
Min. drill pipe ID required: |
in |
|
(Check valve) |
Connection type: |
|
|
NC-50 (4 ½ IF) |
Working pressure rating: |
psi |
|
15,000 |
|
|
|
|
Quantity: |
no. |
|
2 |
Make: |
|
|
VAM-(Omsco) |
OD: |
in |
|
7 |
Min. drill pipe ID required: |
in |
|
(check valve) |
Connection type: |
|
|
5 7/8 Turbotorque 585 |
Working pressure rating: |
psi |
|
15,000 |
|
|
|
|
D.1.16 Fast Shut-Off Coupling |
|
|
|
|
|
|
|
Make/type: |
|
|
N/A |
Quantity: |
no. |
|
N/A |
Size tool joint to fit: |
in |
|
N/A |
|
|
|
|
D.1.17 Circulation Head |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make/type: |
|
|
N/A |
Valve make: |
|
|
N/A |
Valve type: |
|
|
N/A |
Valve size (ID): |
in |
|
N/A |
Valve working pressure: |
psi |
|
N/A |
Bottom connection type: |
|
|
N/A |
Top connection type: |
|
|
N/A |
Wireline stripper: |
yes/no |
|
N/A |
|
|
|
|
D.1.18 IBOP Valves |
|
|
|
|
|
|
|
Upper: |
|
|
|
Quantity: |
no. |
|
2 |
Make/type: |
|
|
Hydrill |
Working pressure: |
psi |
|
15 Kpsi |
Max. OD body: |
in |
|
8-5/8 |
Min. ID body: |
in |
|
3-1/16 |
Connection type: |
|
|
7-5/8Reg |
|
|
|
|
Lower: |
|
|
|
Quantity: |
no. |
|
2 |
Make/type: |
|
|
Hydrill |
Working pressure: |
psi |
|
15 Kpsi |
Max. OD body: |
in |
|
8-5/8 |
Min. ID body: |
in |
|
3-1/16 |
Connection type: |
|
|
7-5/8Reg |
|
|
|
|
D.1.19 Circulation Subs |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
VAM |
OD body: |
in |
|
8 ½ |
Ball size: |
in |
|
Side Entry Type 2 Weco 1502 |
Dressing kits: |
no. |
|
Side Entry Type |
Connection type: |
|
|
6 5/8 FH |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Vam |
OD body: |
in |
|
5 7/8 |
Ball size: |
in |
|
Side Entry Type 2 Weco 1502 |
Dressing kits: |
no. |
|
Side Entry Type |
Connection type: |
|
|
Turbotorque 585 |
|
|
|
|
D.1.20 Cup Type Testers |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make: |
|
|
N/A |
Size test cup for casing weight: |
in-lb/ft |
|
N/A |
Size test cup for casing weight: |
in-lb/ft |
|
N/A |
Size test cup for casing weight: |
in-lb/ft |
|
N/A |
Connection: |
|
|
N/A |
|
|
|
|
D.1.21 Plug Type Testers |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make: |
|
|
N/A |
Size test plugs: |
in |
|
N/A |
Connection: |
|
|
N/A |
|
|
|
|
D.1.22 Drop-In Valves |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 |
For nom. OD drillpipe: |
in |
|
5 7/8 Turbotorque |
Make/type: |
|
|
Hydrill |
Max. OD of dart.: |
in |
|
TBA |
|
|
|
|
Quantity: |
no. |
|
2 |
For nom. OD drillpipe: |
in |
|
5 GPDS50 |
Make/type: |
|
|
Hydrill |
Max. OD of dart.: |
in |
|
TBA |
|
|
|
|
D.1.23 Bit Subs (Box-Box) |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 |
OD size: |
in |
|
9 ½ |
ID size: |
in |
|
3 |
Top connection: |
|
|
7 5/8 Reg |
Bottom connection: |
|
|
7 5/8 Reg |
Bored for float valve: |
yes/no |
|
Yes |
Float size: |
in |
|
5F-6R |
|
|
|
|
Quantity: |
no. |
|
2 |
OD size: |
in |
|
9 ½ |
ID size: |
in |
|
3 |
Top connection: |
|
|
7 5/8 Reg |
Bottom connection: |
|
|
6 5/8 REG |
Bored for float valve: |
yes/no |
|
Yes |
Float size: |
in |
|
5F-6R |
|
|
|
|
Quantity: |
no. |
|
4 |
OD size: |
in |
|
8 ¼ |
ID size: |
in |
|
3 |
Top connection: |
|
|
6 5/8 Reg |
Bottom connection: |
|
|
6 5/8 Reg |
Bored for float valve: |
yes/no |
|
Yes |
Float size: |
in |
|
5F-6R |
|
|
|
|
Quantity: |
no. |
|
2 |
OD size: |
in |
|
7 |
ID size: |
in |
|
2 13/16 |
Top connection: |
|
|
TurboTorque 585 |
Bottom connection: |
|
|
4 ½ REG |
Bored for float valve: |
yes/no |
|
Yes |
Float size: |
in |
|
4R |
|
|
|
|
Quantity: |
no. |
|
2 |
OD size: |
in |
|
6 3/4 |
ID size: |
in |
|
2 13/16 |
Top connection: |
|
|
GPDS50 |
Bottom connection: |
|
|
4 ½ Reg |
Bored for float valve: |
yes/no |
|
Yes |
Float size: |
in |
|
4 R |
|
|
|
|
D.1.24 Crossover Subs |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 |
OD size (max/min): |
in/in |
|
8 ¼ x 6 5/8 |
ID size: |
in |
|
3 |
Top connection size: |
|
|
6 5/8 Reg |
Type (pin/box): |
|
|
Box |
Bottom connection size: |
|
|
GPDS50 |
Type (pin/box): |
|
|
Box |
|
|
|
|
Quantity: |
no. |
|
NA |
OD size (max/min): |
in/in |
|
|
ID size: |
in |
|
|
Top connection size: |
|
|
|
Type (pin/box): |
|
|
|
Bottom connection size: |
|
|
|
Type (pin/box): |
|
|
|
|
|
|
|
Quantity: |
no. |
|
NA |
OD size (max/min): |
in/in |
|
|
ID size: |
in |
|
|
Top connection size: |
|
|
|
Type (pin/box): |
|
|
|
Bottom connection size: |
|
|
|
Type (pin/box): |
|
|
|
|
|
|
|
Quantity: |
no. |
|
NA |
OD size (max/min): |
in/in |
|
|
ID size: |
in |
|
|
Top connection size: |
|
|
|
Type (pin/box): |
|
|
|
Bottom connection size: |
|
|
|
Type (pin/box): |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 |
OD size (max/min): |
in/in |
|
8 ¼ x 9 ½ |
ID size: |
in |
|
3 |
Top connection size: |
|
|
6 5/8 Reg |
Type (pin/box): |
|
|
Box |
Bottom connection size: |
|
|
7 5/8 Reg |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 |
OD size (max/min): |
in/in |
|
9 ½ x 8 ¼ |
ID size: |
in |
|
3 |
Top connection size: |
|
|
7 5/8 Reg |
Type (pin/box): |
|
|
Box |
Bottom connection size: |
|
|
6 5/8 Reg |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 |
OD size (max/min): |
in/in |
|
9 ½ x 8 1/2 |
ID size: |
in |
|
3 |
Top connection size: |
|
|
7 5/8 Reg |
Type (pin/box): |
|
|
Box |
Bottom connection size: |
|
|
6 5/8 FH |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
4 |
OD size (max/min): |
in/in |
|
8 1/2 x 9 ½ |
ID size: |
in |
|
3 |
Top connection size: |
|
|
6 5/8 FH |
Type (pin/box): |
|
|
Box |
Bottom connection size: |
|
|
7 5/8 Reg |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
4 |
OD size (max/min): |
in/in |
|
8 ½ x 8 ¼ |
ID size: |
in |
|
3 |
Top connection size: |
|
|
6 5/8 FH |
Type (pin/box): |
|
|
Box |
Bottom connection size: |
|
|
6 5/8 Reg |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 |
OD size (max/min): |
in/in |
|
8 ¼ x 7 |
ID size: |
in |
|
3 |
Top connection size: |
|
|
6 5/8 Reg |
Type (pin/box): |
|
|
Box |
Bottom connection size: |
|
|
5 7/8 Turbotorque 585 |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 |
OD size (max/min): |
in/in |
|
6 ¾ |
ID size: |
in |
|
2 13/16 |
Top connection size: |
|
|
5 GPDS50 |
Type (pin/box): |
|
|
Box |
Bottom connection size: |
|
|
4 1/2 Reg |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 |
OD size (max/min): |
in/in |
|
6 ¾ x 5 |
ID size: |
in |
|
2 |
Top connection size: |
|
|
5 GPDS50 |
Type (pin/box): |
|
|
Box |
Bottom connection size: |
|
|
NC 38 |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 |
OD size (max/min): |
in/in |
|
7 x 8 ½ |
ID size: |
in |
|
3 1/16 |
Top connection size: |
|
|
5 7/8 Turbotorque 585 |
Type (pin/box): |
|
|
Box |
Bottom connection size: |
|
|
6 5/8 FH |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
4 |
OD size (max/min): |
in/in |
|
7 x 8 1/4 |
ID size: |
in |
|
3 |
Top connection size: |
|
|
5 7/8 Turbotorque 585 |
Type (pin/box): |
|
|
Box |
Bottom connection size: |
|
|
6 5/8 Reg |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 |
OD size (max/min): |
in/in |
|
7 x 9 ½ |
ID size: |
in |
|
3 |
Top connection size: |
|
|
5 7/8 Turbotorque 585 |
Type (pin/box): |
|
|
Box |
Bottom connection size: |
|
|
7 5/8 Reg |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 |
OD size (max/min): |
in/in |
|
6 3/4 x 8 ½ |
ID size: |
in |
|
2 13/16 |
Top connection size: |
|
|
5 GPDS50 |
Type (pin/box): |
|
|
Box |
Bottom connection size: |
|
|
6 5/8 FH |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 |
OD size (max/min): |
in/in |
|
8 ¼ |
ID size: |
in |
|
3 |
Top connection size: |
|
|
6 5/8 Reg |
Type (pin/box): |
|
|
Pin |
Bottom connection size: |
|
|
6 5/8 Reg |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 |
OD size (max/min): |
in/in |
|
7 |
ID size: |
in |
|
3 |
Top connection size: |
|
|
5 7/8 Turbotorque 585 |
Type (pin/box): |
|
|
Pin |
Bottom connection size: |
|
|
5 7/8 Turbotorque |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 |
OD size (max/min): |
in/in |
|
8 1/2 |
ID size: |
in |
|
3 |
Top connection size: |
|
|
6 5/8 FH |
Type (pin/box): |
|
|
Pin |
Bottom connection size: |
|
|
6 5/8 FH |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 |
OD size (max/min): |
in/in |
|
6 3/4 |
ID size: |
in |
|
2 13/16 |
Top connection size: |
|
|
4 ½ Reg |
Type (pin/box): |
|
|
Pin |
Bottom connection size: |
|
|
5 GPDS50 |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 |
OD size (max/min): |
in/in |
|
4 3/4 |
ID size: |
in |
|
2 ¼ |
Top connection size: |
|
|
3 1/2 Reg |
Type (pin/box): |
|
|
Pin |
Bottom connection size: |
|
|
3 ½ NC38 |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 |
OD size (max/min): |
in/in |
|
6 3/4 |
ID size: |
in |
|
2 13/16 |
Top connection size: |
|
|
5 GPDS50 |
Type (pin/box): |
|
|
Pin |
Bottom connection size: |
|
|
5 GPDS50 |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 Circulating sub |
OD size (max/min): |
in/in |
|
8 ½ |
ID size: |
in |
|
|
Top connection size: |
|
|
2 Weco 1502 Female (non-wing) |
Type (pin/box): |
|
|
|
Bottom connection size: |
|
|
6 5/8 FH |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 Circulating sub |
OD size (max/min): |
in/in |
|
8 ½ |
ID size: |
in |
|
|
Top connection size: |
|
|
2 Weco 1502 Female (non-wing) |
Type (pin/box): |
|
|
|
Bottom connection size: |
|
|
6 5/8 FH |
Type (pin/box): |
|
|
Box |
|
|
|
|
Quantity: |
no. |
|
2 Circulating sub |
OD size (max/min): |
in/in |
|
7 |
ID size: |
in |
|
|
Top connection size: |
|
|
2 Weco 1502 Female (non-wing) |
Type (pin/box): |
|
|
|
Bottom connection size: |
|
|
5 7/8 Turbotorque585 |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 Circulating sub |
OD size (max/min): |
in/in |
|
7 |
ID size: |
in |
|
|
Top connection size: |
|
|
2 Weco 1502 Female (non-wing) |
Type (pin/box): |
|
|
|
Bottom connection size: |
|
|
5 7/8 Turbotorque585 |
Type (pin/box): |
|
|
Box |
Quantity: |
no. |
|
2 Circultaing sub |
OD size (max/min): |
in/in |
|
6 ¾ |
ID size: |
in |
|
|
Top connection size: |
|
|
2 Weco 1502 Female (non-wing) |
Type (pin/box): |
|
|
|
Bottom connection size: |
|
|
5 GPDS50 |
Type (pin/box): |
|
|
Pin |
|
|
|
|
Quantity: |
no. |
|
2 Circulating sub |
OD size (max/min): |
in/in |
|
6 ¾ |
ID size: |
in |
|
|
Top connection size: |
|
|
2 Weco 1502 Female (non-wing) |
Type (pin/box): |
|
|
|
Bottom connection size: |
|
|
5 GPDS50 |
Type (pin/box): |
|
|
Box |
|
|
|
|
Quantity: |
no. |
|
2 Double Side Entry sub |
OD size (max/min): |
in/in |
|
7 |
ID size: |
in |
|
2 |
Top connection size: |
|
|
2 x 2 Weco 1502 Female (non wing) |
Type (pin/box): |
|
|
5 7/8 Turbotorque 585 (Pin) |
Bottom connection size: |
|
|
|
Type (pin/box): |
|
|
|
|
|
|
|
D.1.25 Drilling Bumper Subs |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 + 1 |
Make: |
|
|
TBA |
OD: |
in |
|
8 + 6 1/2 |
Stroke: |
in |
|
60 |
Connection type: |
|
|
6 5/8 Reg + NC50 |
|
|
|
|
D.1.26 Hole Openers |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make: |
|
|
N/A |
OD: |
in |
|
N/A |
Connection type: |
|
|
N/A |
|
|
|
|
D.1.27 Undereamer |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make/type: |
|
|
N/A |
OD Min/OD Max: |
in/in |
|
N/A |
Connection type: |
|
|
N/A |
|
|
|
|
D.2 HANDLING TOOLS |
|
|
|
|
|
|
|
D.2.1 Drill Pipe Elevators |
|
|
|
|
|
|
|
Size: |
in |
|
9 ½ DC, 8 ¼ DC, 6 ¾ DC, 6 5/8 DP, |
Quantity: |
no. |
|
2 each |
Make: |
|
|
Blohm&Voss |
Model: |
|
|
VES-SD 500 T/750 T (Hydr) |
Rated capacity: |
st |
|
500 ton/ 750 ton (square shoulder only) |
Size: |
in |
|
6 5/8 DP, 5 7/8 DP, 5 DP, 3 ½ DP (inserts for) |
Quantity: |
no. |
|
2 Sets |
Make: |
|
|
Blohm&Voss |
Model: |
|
|
VES-CL-500 (Hydr) |
Rated capacity: |
st |
|
500 T |
|
|
|
|
Size: |
in |
|
6 5/8 |
Quantity: |
no. |
|
1 |
Make: |
|
|
Blohm&Voss |
Model: |
|
|
CL-1000 (Hydr) |
Rated capacity: |
st |
|
1000 T |
|
|
|
|
D.2.2 Drill Collar Elevators |
|
|
|
|
|
|
|
Size: |
in |
|
N/A |
Quantity: |
no. |
|
N/A |
Make: |
|
|
N/A |
Model: |
|
|
N/A |
Rated capacity: |
st |
|
N/A |
|
|
|
|
D.2.3 Tubing Elevators |
|
|
|
|
|
|
|
Size (max/min): |
in/in |
|
N/A |
Quantity: |
no. |
|
N/A |
Make: |
|
|
N/A |
Model: |
|
|
N/A |
Rated capacity: |
st |
|
N/A |
|
|
|
|
D.2.4 Drill Pipe Hand Slips |
|
|
|
|
|
|
|
Size: |
in |
|
6 5/8 750 Ton |
Quantity: |
no. |
|
2 |
Make/type: |
|
|
Blohm&Voss / LRS |
|
|
|
|
Size: |
in |
|
5 7/8 750 Ton |
Quantity: |
no. |
|
2 |
Make/type: |
|
|
Blohm&Voss / LRS |
|
|
|
|
Size: |
in |
|
5 750 Ton |
Quantity: |
no. |
|
2 |
Make/type: |
|
|
Blohm&Voss / LRS |
|
|
|
|
Size: |
in |
|
3 ½ |
Quantity: |
no. |
|
2 |
Make/type: |
|
|
Blohm&Voss / RSM |
|
|
|
|
D.2.5 Semi-Automatic DP Slips |
|
|
|
|
|
|
|
Size range (largest/smallest): |
in/in |
|
DC 9 ½, 8 ¼, 6 ¾, 4 3/4 (inserts) DP 5, 5 ½, 5 7/8, 6 5/8 (inserts) |
Quantity: |
no. |
|
2 |
Make/type: |
|
|
Blohm&Voss PS 1000 (1000 Ton) |
D.2.6 Drill Collar Slips |
|
|
|
|
|
|
|
Size: |
in |
|
8 ½ to 10 |
Quantity: |
no. |
|
2 |
Make/type: |
|
|
Blohm&Voss / DCL |
|
|
|
|
Size: |
in |
|
8 9 ½ |
Quantity: |
no. |
|
2 |
Make/type: |
|
|
Blohm&Voss / DCL |
|
|
|
|
Size: |
in |
|
5 ½ to 7 |
Quantity: |
no. |
|
2 |
Make/type: |
|
|
Blohm&Voss / DCM |
|
|
|
|
Size: |
in |
|
4 ½ - 6 |
Quantity: |
no. |
|
2 |
Make/type: |
|
|
Blohm&Voss / DCM |
|
|
|
|
D.2.7 Drill Collar Safety Clamps |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 Blohm&Voss / C-Clamp |
Range: |
in-in |
|
4 ½ - 5 5/8 |
|
|
|
|
Quantity: |
no. |
|
2 Blohm&Voss / C-Clamp |
Range: |
in-in |
|
9 ½ - 10 5/8 |
|
|
|
|
Quantity: |
no. |
|
1 Blohm&Voss / C-Clamp + air kit |
Range: |
in-in |
|
29 ½ - 30 ½ |
|
|
|
|
D.2.8 Tubing Slips |
|
|
|
|
|
|
|
Size: |
in |
|
N/A |
Quantity: |
no. |
|
N/A |
Make/type: |
|
|
N/A |
|
|
|
|
D.2.9 Tubing Spider |
|
|
|
|
|
|
|
Slip size (max/min): |
in/in |
|
N/A |
Quantity: |
no. |
|
N/A |
Make: |
|
|
N/A |
Adapter Plate: |
|
|
N/A |
|
|
|
|
D.2.10 Drill Collar Lifting Subs |
|
|
|
|
|
|
|
Quantity: |
no. |
|
8 |
For OD DC: |
in |
|
9 ½ |
Connection Type: |
|
|
7 5/8 Reg Pin |
|
|
|
|
Quantity: |
no. |
|
14 |
For OD DC: |
in |
|
8 ¼ |
Connection Type: |
|
|
6 5/8 Reg Pin |
|
|
|
|
Quantity: |
no. |
|
12 |
For OD DC: |
in |
|
6 ¾ |
Connection Type: |
|
|
4 ½ If Pin |
|
|
|
|
Quantity: |
no. |
|
10 |
For OD DC: |
in |
|
4 ¾ |
Connection Type: |
|
|
3 ½ If Pin |
D.2.11 DC/DP Lifting Plugs |
|
|
|
|
|
|
|
Quantity: |
no. |
|
63 |
For OD DC: |
in |
|
9 ½ - 8 ¼ - 6 ¾ -4 ¾ |
Connection Type: |
|
|
7 5/8 Reg 6 5/8 Reg 6 5/8 FH 5 7/8 TT585 5 GPDS50 4 ½ reg NC38 |
|
|
|
|
D.2.12 Bit Breakers |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
For bit size: |
in |
|
26 |
|
|
|
|
Quantity: |
no. |
|
1 + 1 |
For bit size: |
in |
|
17 ½ + 16 |
|
|
|
|
Quantity: |
no. |
|
1 |
For bit size: |
in |
|
12 ¼ |
|
|
|
|
Quantity: |
no. |
|
1 |
For bit size: |
in |
|
8 ½ |
|
|
|
|
Quantity: |
no. |
|
1 |
For bit size: |
in |
|
6 |
|
|
|
|
D.2.13 Elevator Links |
|
|
|
|
|
|
|
Quantity of sets: |
no. |
|
1 |
Make/type: |
|
|
NOV-Varco |
Size: |
in |
|
5 ½ |
Length: |
in |
|
200 |
Rated capacity: |
st |
|
1000 |
|
|
|
|
Quantity of sets: |
no. |
|
1 |
Make/type: |
|
|
NOV-Varco |
Size: |
in |
|
3 ½ |
Length: |
in |
|
144 |
Rated capacity: |
st |
|
500 |
|
|
|
|
Quantity of sets: |
no. |
|
1+1 |
Make/type: |
|
|
NOV-Varco |
Size: |
in |
|
2 ¾ |
Length: |
in |
|
72 + 45 |
Rated capacity: |
st |
|
350 |
|
|
|
|
Quantity of sets: |
no. |
|
1 |
Make/type: |
|
|
Blohm&Voss |
Size: |
in |
|
4 ¾ |
Length: |
in |
|
180 |
Rated capacity: |
st |
|
750 |
|
|
|
|
D.2.14 Kelly Spinner |
|
|
|
|
|
|
|
Make/type: |
|
|
N/A |
D.2.15 Drillpipe Spinner |
|
|
| |
|
|
|
| |
Make/type: |
|
|
NOV- Hydratong MPT | |
Size (max/min): |
in/in |
|
3 ½ 9 ¾ | |
|
|
|
| |
D.2.16 Mud Bucket |
|
|
| |
|
|
|
| |
Make: |
|
|
NOV - Hydratong with Mud Bucket. Hydraulic operated | |
Size: |
in |
|
2 7/8 9 ¾ | |
|
|
|
| |
D.2.17 Hydraulic Make-Up/Breakout Machine (e.g. Ezy Torque) |
|
| ||
|
|
|
| |
Make/type: |
|
|
NOV | |
Maximum line pull: |
st |
|
16,674 st (146 Kn) | |
|
|
|
| |
D.2.18 Rotary Rig Tongs |
|
|
| |
|
|
|
| |
Quantity (sets): |
no. |
|
2 | |
Make/type: |
|
|
Blohm&Voss / BV-100 | |
Size range (max OD/min OD): |
in/in |
|
4 to 12 | |
Torque rating: |
ft-lbs |
|
100,000 | |
|
|
|
| |
D.2.19 Tubing Tongs (manual) |
|
|
| |
|
|
|
| |
Quantity (sets): |
no. |
|
N/A | |
Make/type: |
|
|
N/A | |
Size range (max OD/min OD): |
in/in |
|
N/A | |
Torque rating: |
ft-lbs |
|
N/A | |
|
|
|
| |
D.2.20 Tubing Tong Power |
|
|
| |
|
|
|
| |
Quantity: |
no. |
|
1 Insert for Hydratong (iron roughneck) | |
Make/type: |
|
|
Farr KT 7585 | |
Size range (max OD/min OD): |
in/in |
|
2 3/8 to 8 5/8 | |
Max output torque: |
ft-lbs |
|
25,000 | |
Torque indicator: |
yes/no |
|
Yes | |
Back-up arm: |
yes/no |
|
Yes | |
|
|
|
| |
Quantity: |
no. |
|
1 Insert for Hydratong (iron roughneck) | |
Make/type: |
|
|
Farr KT2000 | |
Size range (max OD/min OD): |
in/in in/in |
|
8 5/8 to 20 | |
Max output torque: |
ft-lbs |
|
50,700 | |
Torque indicator: |
yes/no |
|
Yes | |
Back-up arm: |
yes/no |
|
Yes | |
|
|
|
| |
D.2.21 Iron Roughneck |
|
|
| |
|
|
|
| |
Make/type: |
|
|
Hydratong MPT TF-975 w/ TE-1190 (2 each) | |
Size range (max OD/min OD): |
in/in |
|
3 ½ to 9 ¾ | |
Max output torque: |
ft-lbs |
|
147,000 | |
|
|
|
| |
D.3 FISHING EQUIPMENT |
|
|
| |
|
|
|
| |
D.3.1 Overshots |
|
|
| |
|
|
|
| |
Quantity: |
no. |
|
1 | |
Make/type: |
|
|
Bowen 150 FS | |
Overshot OD: |
in |
|
11 ¾ |
To catch size: |
in |
|
4 7/8 to 10 1/8 |
Overshot guide OD: |
in |
|
11 ¾ |
Extension sub length: |
in |
|
36 , 60 |
Lipped guide (oversize, Regular): |
|
|
15 , 22 |
Grapples (spiral, basket, both): |
|
|
To fish contractors new + used tubelars |
Pack offs: |
yes/no |
|
Yes |
Top sub connection type: |
|
|
6 5/8 Reg Box |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen 150 FS |
Overshot OD: |
in |
|
9 5/8 |
To catch size: |
in |
|
4 7/8 to 8 |
Overshot guide OD: |
in |
|
9 5/8 |
Extension sub length: |
in |
|
36 , 48 |
Lipped guide (oversize, Regular): |
|
|
15 |
Grapples (spiral, basket, both): |
|
|
To fish contractors new + used tubelars |
Pack offs: |
yes/no |
|
yes |
Top sub connection type: |
|
|
6 5/8 Reg Box |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen 150 SH |
Overshot OD: |
in |
|
8 1/8 |
To catch size: |
in |
|
4 7/8 to 7 |
Overshot guide OD: |
in |
|
8 1/8 |
Extension sub length: |
in |
|
42 |
Lipped guide (oversize, Regular): |
|
|
Standard 8 1/8 |
Grapples (spiral, basket, both): |
|
|
Spiral 7, 6 7/8, 6 ¾, 6 5/8 |
Pack offs: |
yes/no |
|
Yes |
Top sub connection type: |
|
|
4 ½ IF Box |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen 150 FS |
Overshot OD: |
in |
|
7 7/8 reinforced to 8 1/8 ( FS) |
To catch size: |
in |
|
4 7/8 to 6 3/4 |
Overshot guide OD: |
in |
|
8 1/8 |
Extension sub length: |
in |
|
42 |
Lipped guide (oversize, Regular): |
|
|
|
Grapples (spiral, basket, both): |
|
|
To fish contractors new + used tubelars |
Pack offs: |
yes/no |
|
Yes |
Top sub connection type: |
|
|
4 ½ IF Box |
|
|
|
|
D.3.2 Hydraulic Fishing Jar |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen / Type Z #52711/015 |
OD body: |
in |
|
8 |
Min. ID: |
in |
|
3 1/16 |
Stroke: |
in |
|
20 |
Connection type: |
|
|
6 5/8 REG |
Repair kit: |
yes/no |
|
Yes |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen / Type Z #5244/015 |
OD body: |
in |
|
6 ½ |
Min. ID: |
in |
|
2 ¼ |
Stroke: |
in |
|
20 |
Connection type: |
|
|
4 1/2IF |
Repair kit: |
yes/no |
|
Yes |
|
|
|
|
D.3.3 Jar Intensifier |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make: |
|
|
Bowen # 55910/006 |
Type: |
|
|
Jar intensifier |
OD body: |
in |
|
8 |
Min. ID: |
in |
|
3 1/16 |
Connection type: |
|
|
6 5/8 Reg |
Repair kit: |
yes/no |
|
Yes |
|
|
|
|
Quantity: |
no. |
|
1 |
Make: |
|
|
Bowen # 55905/010 |
Type: |
|
|
Jar intensifier |
OD body: |
in |
|
6 ½ |
Min. ID: |
in |
|
2 1/4 |
Connection type: |
|
|
4 ½ IF |
Repair kit: |
yes/no |
|
Yes |
|
|
|
|
D.3.4 Surface Jar |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make/type: |
|
|
N/A |
OD body: |
in |
|
N/A |
Stroke: |
in |
|
N/A |
Connection type: |
|
|
N/A |
Repair kit: |
yes/no |
|
N/A |
|
|
|
|
D.3.5 Fishing Bumper subs |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen / Fishing bumper sub # 26595/005 |
OD body: |
in |
|
8 |
Min. ID: |
in |
|
3 ½ |
Stroke: |
in |
|
20 |
Connection type: |
|
|
6 5/8 REG |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen / Fishing bumper sub # 10257/007 |
OD body: |
in |
|
6 ½ |
Min. ID: |
in |
|
2 ¼ |
Stroke: |
in |
|
20 |
Connection type: |
|
|
4 ½ IF |
|
|
|
|
D.3.6 Safety Joints |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen / Safety Joint |
OD body: |
in |
|
8 |
Min. ID: |
in |
|
3 ½ |
Stroke: |
in |
|
N/A |
Connection type: |
|
|
6 5/8 FH |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen / Safety Joint # 149406/009 |
OD body: |
in |
|
6 ½ |
Min. ID: |
in |
|
3 ¾ |
Stroke: |
in |
|
N/A |
Connection type: |
|
|
4 ½ IF |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen / Safety Joint |
OD body: |
in |
|
7 |
Min. ID: |
in |
|
TBA |
Stroke: |
in |
|
N/A |
Connection type: |
|
|
5 7/8 Turbotorque 585 |
|
|
|
|
D.3.7 Junk Baskets (Reverse Circulation) |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen # 2708/005 |
For hole size: |
in |
|
17 ½ |
OD body: |
in |
|
15 |
Connection type: |
|
|
6 5/8 Reg |
Inside magnet available: |
yes/no |
|
Yes |
Mill shoes type B |
yes/no |
|
Yes |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen # 2690/005 |
For hole size: |
in |
|
12 ¼ |
OD body: |
in |
|
11 ¾ |
Connection type: |
|
|
6 5/8 Reg |
Inside magnet available: |
yes/no |
|
Yes |
Mill shoes type B: |
yes/no |
|
Yes |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen # 2567/009 |
For hole size: |
in |
|
8 ½ |
OD body: |
in |
|
8 ¼ |
Connection type: |
|
|
4 ½ IF |
Inside magnet available: |
yes/no |
|
Yes |
Mill shoes type B: |
yes/no |
|
Yes |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen |
For hole size: |
in |
|
8 ½ |
OD body: |
in |
|
6 5/8 |
Connection type: |
|
|
4 ½ IF |
Inside magnet available: |
yes/no |
|
Yes |
Mill shoes type B: |
yes/no |
|
Yes |
|
|
|
|
D.3.8 Junk Subs |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen # 15485/006 |
For hole size: |
in |
|
12 ¼ |
OD body: |
in |
|
9 5/8 |
Connection type: |
|
|
6 5/8 Reg |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen # 15475/005 |
For hole size: |
in |
|
8 ½ |
OD body: |
in |
|
7 |
Connection type: |
|
|
4 ½ REG |
|
|
|
|
D.3.9 Flat Bottom Junk Mill |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen |
OD flat mill: |
in |
|
14 ¾ |
Connection type: |
|
|
7 5/8 REG Pin |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen # 41695/120 |
OD flat mill: |
in |
|
12 |
Connection type: |
|
|
6 5/8 REG Pin |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen # 41665/018 |
OD flat mill: |
in |
|
8 1/8 |
Connection type: |
|
|
4 ½ REG Pin |
|
|
|
|
D.3.10 Magnet Fishing Tools |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen # 32310/005 |
OD body: |
in |
|
8 |
Connection type: |
|
|
4 ½ REG Pin |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen # 32370/005 |
OD body: |
in |
|
11 ½ |
Connection type: |
|
|
6 5/8 REG Pin |
|
|
|
|
D.3.11 Taper Taps |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen # 15243/049 |
OD (Max/Min): |
in/in |
|
1 ¾ to 4 ¾ |
OD body: |
in |
|
7 ¾ |
Length: |
in |
|
49 |
Connection type: |
|
|
6 5/8 REG Box |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Bowen # 15240/038 |
OD (Max/Min): |
in/in |
|
1 13/16 to 3 11/16 |
OD body: |
in |
|
6 3/4 |
Length: |
in |
|
38 |
Connection type: |
|
|
4 ½ IF Box |
|
|
|
|
D.3.12 Die Collars |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make/type: |
|
|
N/A |
OD (Max/Min): |
in/in |
|
N/A |
OD body: |
in |
|
N/A |
Length: |
ft |
|
N/A |
Connection type: |
|
|
N/A |
E. WELL CONTROL / SUBSEA EQUIPMENT |
|
| |
|
|
|
|
E.1 LOWER RISER DIVERTER ASSEMBLY (used when drilling for the surface casing) |
|
| |
|
|
|
|
E.1.1 Hydraulic Connector |
|
|
|
|
|
|
|
Size: |
in |
|
N/A |
Make: |
|
|
N/A |
Surface controlled hydraulic operated dump valves: |
no. |
|
N/A |
Size: |
in |
|
N/A |
|
|
|
|
E.1.2 Flex Joint/Riser Adapter |
|
|
|
|
|
|
|
Flex joint |
|
|
|
Make/type: |
|
|
N/A |
Size: |
in |
|
N/A |
Max. deflection: |
degrees |
|
N/A |
|
|
|
|
Riser adapter: |
|
|
|
Make/type: |
|
|
N/A |
Size: |
in |
|
N/A |
|
|
|
|
E.2 PRIMARY BOP STACK (from bottom to top) |
|
|
|
|
|
|
|
Stack complete with |
|
|
|
-guide frame: |
yes/no |
|
Yes |
-pick up attachment |
yes/no |
|
Yes for LMRP, No for stack alone. |
-transport base: |
yes/no |
|
Yes |
Size (bore): |
in |
|
18-3/4 |
Working pressure: |
psi |
|
15,000 |
H2S service: |
yes/no |
|
Yes |
|
|
|
|
E.2.1 Alternate Hydraulic Connector |
|
|
|
|
|
|
|
Alternate connector available: |
yes/no |
|
No |
Connector make/model: |
|
|
|
Adapter available: |
yes/no |
|
No, our connector is set for 27 only |
|
|
|
|
E.2.2 Hydraulic Wellhead Connector |
|
|
|
|
|
|
|
Size: |
in |
|
18-3/4 |
Make/type: |
|
|
Vetco style SHD (H4) |
Working pressure: |
psi |
|
15,000 |
Hot tap for underwater intervention: |
yes/no |
|
Yes |
Spare Connector same type: |
yes/no |
|
No |
|
|
|
|
E.2.3 Ram Type Preventers |
|
|
|
|
|
|
|
Preventers: |
|
|
|
Quantity: |
no. |
|
1 Lower Triple |
Bore size: |
in |
|
18-3/4 |
Working pressure: |
psi |
|
15,000 |
Make: |
|
|
NOV-Shaffer |
Model: |
|
|
NXT |
Type (single/double/Triple): |
|
|
Triple |
Ram locks: |
yes/no |
|
Yes, individually operated |
Preventers connection type - top: |
|
|
Studded, 18-3/4 15,000 psi WP, BX164 |
Preventers connection type - bottom: |
|
|
Flanged, 18-3/4 15,000 psi WP, BX164 |
Side outlets: |
yes/no |
|
Yes |
Size: |
in |
|
3-1/16 |
Connection type: |
|
|
Studded, 3-1/16 15,000 psi WP, BX154 |
|
|
|
|
Preventers: |
|
|
|
Quantity: |
no. |
|
1 Upper Triple |
Bore size: |
in |
|
18-3/4 |
Working pressure: |
psi |
|
15,000 |
Make: |
|
|
NOV-Shaffer |
Model: |
|
|
NXT |
Type (single/double/Triple): |
|
|
Triple |
Ram locks: |
yes/no |
|
Yes (Ultralock II B CL) |
Preventers connection type - top: |
|
|
API flange BX-164 STDD |
Preventers connection type - bottom: |
|
|
API flange BX-164 Flange |
Side outlets: |
yes/no |
|
Yes |
Size: |
in |
|
3-1/16 |
Connection type: |
|
|
Studded, 3-1/16 15,000 psi WP, BX154 |
Blind/shear rams |
|
|
| ||
Quantity: |
no. |
|
1 set of CVX Blind Shears | ||
Quantity: |
no. |
|
1 set of Casing Shear Rams | ||
|
|
|
| ||
Pipe rams: |
|
|
| ||
Quantity: |
no. |
|
2 Sets | ||
|
Size: in |
|
5-7/8 fixed | ||
Variable rams |
|
|
| ||
Quantity: |
no. |
|
2 sets | ||
Size range (min/max): |
in/in |
|
5 7 multi rams | ||
Quantity: |
no. |
|
2 sets | ||
Size range (min/max): |
in/in |
|
3 1/2 5 7/8 multi rams | ||
|
|
|
| ||
E.2.4 Stack Configuration (Blind/Shear/Pipe/Variable) |
|
| |||
|
|
|
| ||
Top rams: |
Ram #1 |
|
|
Shear Blind Rams CVX | |
Top rams: |
Ram #2 |
|
|
Casing Shear rams | |
Top rams: |
Ram #3 |
|
|
Variable 3 1/2- 5 7/8 | |
Spacing between middle lower and lower rams: |
in |
|
| ||
Lower rams: |
Ram#4 |
|
|
Variable 5 7 | |
Lower rams: |
Ram#5 |
|
|
Fixed 9 5/8 (CVX) | |
Lower rams: |
Ram#6 |
|
|
Variable rams 5 - 7 | |
Position of side outlets - kill: |
|
|
| ||
Upper: |
|
|
Below Ram #3 | ||
Lower: |
|
|
Below Ram #5 | ||
Position of side outlets-choke: |
|
|
| ||
Upper: |
|
|
Below Upper Annular | ||
Upper Middle |
|
|
Below Shear Ram # 1 | ||
Lower Mddle |
|
|
Below Ram # 4 | ||
Lower: |
|
|
Below Ram # 6 | ||
|
|
|
| ||
E.2.5 Annular Type Preventer On Stack |
|
|
| ||
|
|
|
| ||
Size: |
in |
|
18 ¾ | ||
Working pressure: |
psi |
|
10,000 | ||
Make/type: |
|
|
18-3/4 10,000 psi WP NOV-Shaffer Wedge Cover Standard Spherical Blowout Preventer | ||
|
|
|
| ||
E.2.6 Mandrel |
|
|
| ||
|
|
|
| ||
Make/type: |
|
|
BOP Mandrel, with a H-4 profile up (Inconel 625 lined VX gasket groove), and an 18-3/4 x 10 ksi WP flange down (Inconel 625 lined BX gasket groove). H2S service in accordance with NACE MR-01-75. | ||
Size: |
in |
|
18-3/4 | ||
|
|
|
| ||
E.2.7 Fail-Safe Hydraulic Valves (Kill and Choke) |
|
|
| ||
|
|
|
| ||
Quantity on each side outlet: |
no. |
|
1x Dual Block (= 2 valves) on each outlet | ||
Size (ID): |
in |
|
3-1/16 | ||
Make/type: |
|
|
Gate Valve, Dual Block, Hydraulic Operated, API-6A, 3-1/16 15,000 psi WP NOV-Shaffer Type HB, 3-1/16 bore, 3-1/16 15,000 psi WP straight body, short sea chest, BX-154 stainless steel lined ring grooves |
Working pressure: |
psi |
|
15,000 |
Solid block: |
yes/no |
|
Yes |
|
|
|
|
E.2.8 Subsea Accumulators (see also E.10.1. Surface Accumulator Unit) |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2x 80 gal for LMRP, 3x110 gal Piston Type Bottle, 6x 7 1/2 gal Depth Compensated Bottles for BOP |
Useful capacity per accumulator (w/o precharge): |
U.S.gal |
|
6x 7 ½ gal DCB, 3x110 gal PTB |
Bottle working pressure: |
psi |
|
7,500 |
|
|
|
|
E.2.9 Hydraulic Control Pod/Receptacles |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 (one for each pod) |
Redundancy: |
% |
|
100 |
Color coded: |
yes/no |
|
Yes |
Remote Regulation of operating pressure for functions requiring lower operating pressure: |
yes/no |
|
Yes Yes |
Spare control pod: |
yes/no |
|
No |
|
|
|
|
E.3 PRIMARY LOWER MARINE RISER PACKAGE (From Bottom to Top) |
|
| |
|
|
|
|
E.3.1 Hydraulic Connector |
|
|
|
|
|
|
|
Make/type: |
|
|
Vetco 18-3/4 Style ExF HAR Modified H4. 15,000 PSI MWP. Studded top x 18-3/4 oflexi 625 lined VX/VT gasket |
Size: |
in |
|
18 ¾ |
Working pressure: |
psi |
|
15,000 |
Hot tap for underwater intervention: |
yes/no |
|
Yes |
Spare connector same type: |
yes/no |
|
No |
|
|
|
|
E.3.2 Annular Type Preventer (LMRP) |
|
|
|
|
|
|
|
Size: |
in |
|
18 ¾ |
Working pressure: |
psi |
|
10,000 |
Make/type: |
|
|
18-3/4 10,000 psi WP NOV-Shaffer Wedge Cover Standard Spherical Blowout Preventer. 18-3/4 vertical bore. Internal H2S trim |
E.3.3 Flex Joint |
|
|
| |
|
|
|
| |
Make/type: |
|
|
Oil States Flexjoint, 18-3/4 -10M | |
Size: |
in |
|
18 ¾ | |
Max deflection: |
degrees |
|
10 deg offset from centre | |
Working pressure |
psi |
|
6,000 | |
Cocking stiffness |
ft-lbs/deg. |
|
30,000 up to 5 ̊, 20,000 at 10 ̊ | |
|
|
|
| |
E.3.4 Riser Adapter |
|
|
| |
|
|
|
| |
Make/type: |
|
|
Riser Adapter, Type « FT-H » x 18-3/4 10M | |
Size: |
in |
|
18 ¾ | |
|
|
|
| |
E.3.5 Connection Lines to Riser |
|
|
| |
|
|
|
| |
Type (rigid loops, oflexip, etc.): |
|
|
Coflexip hoses | |
|
|
|
| |
E.4 SECONDARY BOP STACK (from bottom to top) |
|
Yes | ||
|
|
|
| |
Stack complete with |
|
|
| |
guide frame: |
yes/no |
|
Yes | |
pick up attachment: |
yes/no |
|
Yes for LMRP, No for stack alone. | |
transport base: |
yes/no |
|
Yes | |
Size (bore): |
in |
|
18-3/4 | |
Working pressure: |
psi |
|
15,000 | |
H2S service: |
yes/no |
|
Yes | |
|
|
|
| |
E.4.1 Alternate Hydraulic Connector |
|
|
| |
|
|
|
| |
Alternate connector available: |
yes/no |
|
No | |
Connector make/model: |
|
|
| |
Adapter available: |
yes/no |
|
No, our connector is set for 27 only | |
|
|
|
| |
E.4.2 Hydraulic Wellhead Connector |
|
|
| |
|
|
|
| |
Size: |
in |
|
18-3/4 | |
Make/type: |
|
|
Vetco style SHD (H4) | |
Working pressure: |
psi |
|
15,000 | |
Hot tap for underwater intervention: |
yes/no |
|
Yes | |
Spare connector same type: |
yes/no |
|
No | |
|
|
|
| |
E.4.3 Ram Type Preventers |
|
|
| |
|
|
|
| |
Preventers |
|
|
| |
Quantity: |
no |
|
1 Lower Triple | |
Bore Size: |
in |
|
18-3/4 | |
Working pressure: |
psi |
|
15,000 | |
Make: |
|
|
NOV-Shaffer | |
Model: |
|
|
NXT | |
Type (single/double): |
|
|
Triple | |
Ram locks: |
yes/no |
|
Yes, individually operated | |
Preventers connection type - top: |
|
|
Studded, 18-3/4 15,000 psi WP, BX164 | |
Preventers connection type - bottom: |
|
|
Flanged, 18-3/4 15,000 psi WP, BX164 | |
Side outlets: |
yes/no |
|
Yes | |
Size: |
in |
|
3-1/16 | |
Connection type: |
|
|
Studded, 3-1/16 15,000 psi WP, BX154 | |
|
|
|
| |
Pipe rams |
|
|
| |
Quantity: |
no. |
|
2 Sets |
Size: |
in |
|
5-7/8 fixed |
Quantity: |
no. |
|
|
Size: |
in |
|
|
Quantity: |
no. |
|
|
Size: |
in |
|
|
|
|
|
|
Blind/Shear rams |
|
|
1 set of CVX Blind Shears |
Quantity: |
no. |
|
1 set of Casing Shear Rams |
|
|
|
|
Variable rams |
|
|
|
Quantity: |
no. |
|
2 sets |
Size range (max/min): |
in/in |
|
5 7 multi rams |
Quantity: |
no. |
|
2 sets |
Size range (max/min): |
in/in |
|
3 1/2 5 7/8 multi rams |
|
|
|
|
E.4.4 Stack Configuration (Blind/Shear/Pipe/Variable) |
|
| |
|
|
|
|
Top rams: |
|
|
Shear Blind Rams CVX |
Middle upper rams: |
|
|
Casing Shear rams |
Middle lower rams: |
|
|
Variable 3 1/2- 5 7/8 |
Spacing between Middle Lower and Lower rams: |
in |
|
Variable 5 7 Fixed 9 5/8 (CVX) Variable rams 5 - 7 |
Lower rams: |
|
|
|
|
|
|
|
Position of side outlets-kill: |
|
|
|
Upper: |
|
|
Below Ram #3 |
Lower: |
|
|
Below Ram #5 |
|
|
|
|
Position of side outlets-choke: |
|
|
|
Upper: |
|
|
Below Upper Annular |
Middle: |
|
|
BelowRam #2 |
Lower: |
|
|
Below Ram # 4 |
|
|
|
|
E.4.5 Annular Type Preventer On Stack |
|
|
|
|
|
|
|
Size: |
in |
|
18 ¾ |
Working pressure: |
psi |
|
10,000 |
Make/type: |
|
|
18-3/4 10,000 psi WP NOV-Shaffer Wedge Cover Standard Spherical Blowout Preventer |
|
|
|
|
E.4.6 Mandrel |
|
|
|
|
|
|
|
Make/type: |
|
|
BOP Mandrel, with a H-4 profile up (Inconel 625 lined VX gasket groove), and an 18-3/4 x 10 ksi WP flange down (Inconel 625 lined BX gasket groove). H2S service in accordance with NACE MR-01-75. |
Size: |
in |
|
18-3/4 |
|
|
|
|
E.4.7 Fail-Safe Hydraulic Valves (Kill and Choke) |
|
|
|
|
|
|
|
Quantity on each side outlet: |
no. |
|
1x Dual Block (= 2 valves) on each outlet |
Size (ID): |
in |
|
3-1/16 |
Make/type: |
|
|
Gate Valve, Dual Block, Hydraulic Operated, API-6A, 3-1/16 15,000 psi WP NOV-Shaffer Type HB, 3-1/16 bore, 3-1/16 15,000 psi WP straight body, short sea chest, BX-154 stainless steel lined ring grooves |
Working pressure: |
psi |
|
15,000 |
Solid block: |
yes/no |
|
Yes |
|
|
|
|
E.4.8 Subsea Accumulators (see also E.10.1 Surface Accumulator Unit) |
|
| |
|
|
|
|
Quantity: |
no. |
|
2x 80 gal for LMRP, 3x110 gal Piston Type Bottle, 6x 7 1/2 gal Depth Compensated Bottles for BOP |
Useful capacity per accumulator (w/o precharge): |
U.S.gal |
|
6x 7 ½ gal DCB, 3x110 gal PTB |
Bottle working pressure: |
psi |
|
7,500 |
|
|
|
|
E.4.9 Hydraulic Control Pod/Receptacles |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 (one for each pod) |
Redundancy: |
% |
|
100 |
Color coded: |
yes/no |
|
Yes |
Remote Regulation of operating pressure for functions requiring lower operating pressure: |
yes/no |
|
Yes Yes |
Spare control pod: |
yes/no |
|
No |
|
|
|
|
E.5 SECONDARY LOWER MARINE RISER PACKAGE (From Bottom to Top) |
|
| |
|
|
|
|
E.5.1 Hydraulic Connector |
|
|
|
|
|
|
|
Make/type: |
|
|
Vetco 18-3/4 Style ExF HAR Modified H4. 15,000 PSI MWP. Studded top x 18-3/4 oflexi 625 lined VX/VT gasket |
Size: |
in |
|
18 ¾ |
Working pressure: |
psi |
|
15,000 |
Hot tap for underwater intervention: |
yes/no |
|
Yes |
Spare connector same type: |
yes/no |
|
No |
|
|
|
|
E.5.2 Annular Type Preventer (LMRP) |
|
|
|
|
|
|
|
Size: |
in |
|
18 ¾ |
Working pressure: |
psi |
|
10,000 |
Make/type: |
|
|
18-3/4 10,000 psi WP NOV-Shaffer Wedge Cover Standard Spherical Blowout Preventer. 18-3/4 vertical bore. Internal H2S trim |
E.5.3 Flex Joint |
|
|
|
|
|
|
|
Make/type: |
|
|
Oil States Flexjoint, 18-3/4 -10M |
Size: |
in |
|
18 ¾ |
Max deflection: |
degrees |
|
10 deg offset from centre 6,000 30,000 up to 5 ̊, 20,000 at 10 ̊ |
E.5.4 Riser Adapter |
|
|
|
|
|
|
|
Make/type: |
|
|
|
Size: |
in |
|
Riser Adapter, Type « FT-H » x 18-3/4 10M |
|
|
|
18 ¾ |
E.5.5 Connection Lines to Riser |
|
|
|
|
|
|
|
Type (rigid loops, coflexip, etc): |
|
|
Conduit Coflexip hoses |
|
|
|
|
E.6 PRIMARY MARINE RISER SYSTEM |
|
|
|
|
|
|
|
E.6.1 Marine Riser Joints |
|
|
|
|
|
|
|
Make/model: |
|
|
Shaffer Class H FT-H Type / Slick |
OD: |
in |
|
21 |
ID: |
in |
|
19.25 |
Wall thickness: |
in |
|
15/16 |
Average length of each joint: |
ft |
|
90 |
Weight of one complete joint (in air): |
lbs |
|
36,887 |
Quantity: |
no. |
|
9 |
Pipe material: |
grade |
|
API 5L X80 Seemed pipe |
Minimum yield strength: |
lb |
|
2X106 (coupling rate) |
Type riser connectors: |
|
|
FT-H Type (3,500,000 lbs rated) |
Bolts |
no. |
|
8 |
|
|
|
|
Make/model: |
|
|
Shaffer Class H FT-H Type / Dressed with 2000 ft water depth rated Buoyancy |
OD: |
in |
|
21 |
ID: |
in |
|
19.25 |
Wall thickness: |
in |
|
7/8 |
Average length of each joint: |
ft |
|
90 |
Weight of one complete joint (in air): |
lbs |
|
61,007 |
Quantity: |
no. |
|
18 |
Pipe material: |
grade |
|
API 5L X80 Seemed pipe |
Minimum yield strength: |
lb |
|
2X106 (coupling rate) |
Type riser connectors: |
|
|
FT-H Type (3,500,000 lbs rated) |
Bolts: |
no. |
|
8 |
|
|
|
|
Make/model: |
|
|
Shaffer Class H FT-H Type / Dressed with 4000 ft water depth rated Buoyancy |
OD: |
in |
|
21 |
ID: |
in |
|
19.25 |
Wall thickness: |
in |
|
7/8 |
Average length of each joint: |
ft |
|
90 |
Weight of one complete joint (in air): |
lbs |
|
63,905 |
Quantity: |
no. |
|
22 |
Pipe material: |
grade |
|
API 5L X80 Seemed pipe |
Minimum yield strength: |
lb |
|
2X106 (coupling rate) |
Type riser connectors: |
|
|
FT-H Type (3,500,000 lbs rated) |
Bolts: |
no. |
|
8 |
|
|
|
|
Make/model: |
|
|
Shaffer Class H FT-H Type / Dressed with 6000 ft water depth rated Buoyancy |
OD: |
in |
|
21 |
ID: |
in |
|
19.25 |
Wall thickness: |
in |
|
7/8 |
Average length of each joint: |
ft |
|
90 |
Weight of one complete joint (in air): |
lbs |
|
65,161 |
Quantity: |
no. |
|
22 |
Pipe material: |
grade |
|
API 5L X80 Seemed pipe |
Minimum yield strength: |
lb |
|
2X106 (coupling rate) |
Type riser connectors: |
|
|
FT-H Type (3,500,000 lbs rated) |
Bolts: |
no. |
|
8 |
|
|
|
|
Make/model: |
|
|
Shaffer Class H FT-H Type / Dressed with 8000 ft water depth rated Buoyancy |
OD: |
in |
|
21 |
ID: |
in |
|
19.25 |
Wall thickness: |
in |
|
7/8 |
Average length of each joint: |
ft |
|
90 |
Weight of one complete joint (in air): |
lbs |
|
67,161 |
Quantity: |
no. |
|
22 |
Pipe material: |
grade |
|
API 5L X80 Seemed pipe |
Minimum yield strength: |
lb |
|
2X106 (coupling rate) |
Type riser connectors: |
|
|
FT-H Type (3,500,000 lbs rated) |
Bolts: |
no. |
|
8 |
Make/model: |
|
|
Shaffer Class H FT-H Type / Dressed with 10,000 ft water depth rated Buoyancy |
OD: |
in |
|
21 |
ID: |
in |
|
19.25 |
Wall thickness: |
in |
|
7/8 |
Average length of each joint: |
ft |
|
90 |
Weight of one complete joint (in air): |
lbs |
|
71,161 |
Quantity: |
no. |
|
17 |
Pipe material: |
grade |
|
API 5L X80 Seemed pipe |
Minimum yield strength: |
lb |
|
2X106 (coupling rate) |
Type riser connectors: |
|
|
FT-H Type (3,500,000 lbs rated) |
Bolts: |
no. |
|
8 |
|
|
|
|
Pup |
|
|
|
|
|
|
|
Quantity: |
no. |
|
|
Length: |
ft |
|
1 40, 1 x 25 1x 20 2 x 15 1 x 10 1 x 5 |
Quantity: |
no. |
|
|
Length: |
ft |
|
|
|
|
|
|
Quantity: |
no. |
|
2 (1 x on top of LMRP BOP guide system) |
Length: |
ft |
|
55 |
|
|
|
|
E.6.2 Telescopic Joint |
|
|
2 each (1x back-up onboard) |
|
|
|
|
Make/type: |
|
|
NOV-Shaffer Type FT Telescopic Joint |
Size (ID): |
in |
|
19 3/8 |
Stroke: |
ft |
|
70 |
Double seals: |
yes/no |
|
Yes |
Spare telescoping joint: |
yes/no |
|
Yes |
Location: |
|
|
Rig |
Rotating support ring for riser tensioners: |
type |
|
NOV-Shaffer |
Connection points: |
no. |
|
16 |
E.6.3 Kill/Choke Lines |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 |
Outside diameter: |
in |
|
6 ½ |
Inside diameter: |
in |
|
4 ½ |
Working pressure: |
psi |
|
15,000 |
|
|
|
|
E.6.4 Booster Lines (if Fitted) |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Outside diameter: |
in |
|
5 |
Inside diameter: |
in |
|
4 |
Working pressure: |
psi |
|
7,500 |
|
|
|
|
E.6.5 Hydraulic Supply Lines |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 |
Outside diameter: |
in |
|
2.875 |
Inside diameter: |
in |
|
2.323 |
Working pressure: |
psi |
|
5,000 |
|
|
|
|
E.6.6 Upper Ball (Flex) Joint |
|
|
|
|
|
|
|
Make/type: |
|
|
Oilstates flex type |
Size: |
in |
|
18-3/4 |
Maximum deflection: |
deg. |
|
15 |
Spare upper ball (flex) joint: |
yes/no |
|
No |
|
|
|
|
E.6.7 Buoyancy Modules (if Fitted) |
|
|
|
|
|
|
|
Make: |
|
|
NOV |
Quantity of buoyed riser joints: |
no. |
|
101 |
Riser tub OD: |
in |
|
21 |
OD of buoyed riser joints: |
in |
|
54.5 |
Length of each module: |
ft |
|
13 10 ½ |
Volume of each module: |
ft3 |
|
80.52 (161.04 per pair) |
Buoyancy in seawater: |
st/ft3 |
|
-90 % |
Rated water depth: |
ft |
|
18 x 2k, 22 x 4k, 22 x 6k, 22 x 8k 17 x 10k |
|
|
|
|
E.6.8 Marine Riser Spider |
|
|
|
|
|
|
|
Make/type: |
|
|
NOV-Shaffer Type FT-H Riser Spider, with lower mounting for 60-1/2 rotary table. 1,000 Ton capacity |
|
|
|
|
E.6.9 Marine Riser Gimbal |
|
|
|
|
|
|
|
Make/type: |
|
|
NOV-Shaffer / Heavy Duty 1,000 ton |
|
|
|
|
E.6.10 Riser Handling Tools |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 |
Type: |
|
|
NOV-Shaffer Type FT-H, Hydraulic Running + test tool, 1,000 ton (+solid body NOV elevators) |
E.6.11 Riser Test Tools |
|
|
|
|
|
|
|
Quantity: |
no. |
|
See E.6.10 |
Type: |
|
|
|
|
|
|
|
E.6.12 Instrumented Riser Joint |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make: |
|
|
N/A |
Type: |
|
|
N/A |
Length: |
ft |
|
N/A |
Functions: |
|
|
N/A |
Tension: |
yes/no |
|
N/A |
Mud temp: |
yes/no |
|
N/A |
Mud weight: |
yes/no |
|
N/A |
Other: |
|
|
N/A |
|
|
|
|
E.6.13 Riser Flood/Fill System |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make: |
|
|
N/A |
Type: |
|
|
N/A |
Length: |
ft |
|
N/A |
Automatic operation: |
yes/no |
|
N/A |
Manual override: |
yes/no |
|
N/A |
No. of inlet valves: |
no. |
|
N/A |
Size of valves (ID): |
in |
|
N/A |
|
|
|
|
E.7 SECONDARY MARINE RISER SYSTEM |
|
|
N/A |
|
|
|
|
E.7.1 Marine Riser Joints |
|
|
|
|
|
|
|
Make/model: |
|
|
N/A |
OD: |
in |
|
N/A |
ID: |
in |
|
N/A |
Wall thickness: |
in |
|
N/A |
Average length of each joint: |
ft |
|
N/A |
Weight of one complete joint (in air): |
lbs |
|
N/A |
Quantity: |
no. |
|
N/A |
Pipe material: |
grade |
|
N/A |
Minimum yield strength: |
psi |
|
N/A |
Type riser connectors |
|
|
N/A |
Dogs: |
no. |
|
N/A |
|
|
|
|
Pup joints |
|
|
|
Quantity: |
no. |
|
N/A |
Length: |
ft |
|
N/A |
Quantity: |
no. |
|
N/A |
Length: |
ft |
|
N/A |
Quantity: |
no. |
|
N/A |
Length: |
ft |
|
N/A |
Quantity: |
no. |
|
N/A |
Length: |
ft |
|
N/A |
E.7.2 Telescopic Joint |
|
|
|
|
|
|
|
Make/type: |
|
|
N/A |
Size (ID): |
in |
|
N/A |
Stroke: |
ft |
|
N/A |
Double seals: |
yes/no |
|
N/A |
Spare telescoping joint: |
yes/no |
|
N/A |
Location: |
|
|
N/A |
Rotating support ring for riser tensioners: |
type |
|
N/A |
Connection points: |
no. |
|
N/A |
|
|
|
|
E.7.3 Kill/Choke Lines |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Outside diameter: |
in |
|
N/A |
Inside diameter: |
in |
|
N/A |
Working pressure: |
psi |
|
N/A |
|
|
|
|
E.7.4 Booster Lines (if Fitted) |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Outside diameter: |
in |
|
N/A |
Inside diameter: |
in |
|
N/A |
Working pressure: |
psi |
|
N/A |
|
|
|
|
E.7.5 Hydraulic Supply Lines |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Outside diameter: |
in |
|
N/A |
Inside diameter: |
in |
|
N/A |
Working pressure: |
psi |
|
N/A |
|
|
|
|
E.7.6 Upper Ball (Flex) Joint |
|
|
|
|
|
|
|
Make/type: |
|
|
N/A |
Size: |
in |
|
N/A |
Maximum deflection: |
deg. |
|
N/A |
Spare upper ball (flex) joint: |
yes/no |
|
N/A |
|
|
|
|
E.7.7 Buoyancy Modules (if Fitted) |
|
|
|
|
|
|
|
Make: |
|
|
N/A |
Quantity of buoyed riser joints: |
no. |
|
N/A |
OD of buoyed riser joints: |
in |
|
N/A |
Length of each module: |
ft |
|
N/A |
Volume of each module: |
ft3 |
|
N/A |
Buoyancy in seawater: |
st/ft3 |
|
N/A |
Rated water depth: |
ft |
|
N/A |
|
|
|
|
E.7.8 Marine Riser Spider |
|
|
|
|
|
|
|
Make/type: |
|
|
N/A |
|
|
|
|
E.7.9 Marine Riser Gimbal |
|
|
|
|
|
|
|
Make/type: |
|
|
N/A |
E.7.10 Riser Handling Tools |
|
|
|
Quantity: |
no. |
|
N/A |
Type: |
|
|
N/A |
|
|
|
|
E.7.11 Riser Test Tools |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Type: |
|
|
N/A |
|
|
|
|
E.7.12 Instrumented Riser Joint |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make: |
|
|
N/A |
Type: |
|
|
N/A |
Length: |
ft |
|
N/A |
Functions: |
|
|
N/A |
Tension: |
yes/no |
|
N/A |
Mud temp: |
yes/no |
|
N/A |
Other: |
|
|
N/A |
|
|
|
|
E.7.13 Riser Flood/Fill System |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make: |
|
|
N/A |
Type: |
|
|
N/A |
Length: |
ft |
|
N/A |
Automatic Operation: |
yes/no |
|
N/A |
Manual Override: |
yes/no |
|
N/A |
No. of inlet valves: |
no. |
|
N/A |
Size of Valves (ID): |
in |
|
N/A |
|
|
|
|
E.8 DIVERTER BOP |
|
|
|
(For installation in fixed bell nipple) |
|
|
|
|
|
|
|
Make/type: |
|
|
NOV-Shaffer |
Max. bore size: |
in |
|
21 ¼ |
Working pressure: |
psi |
|
500 |
Number of Diverter outlets: |
no. |
|
2 |
Outlet OD: |
in |
|
3 each 18, 1 each 6 and 1 each 4 |
Insert packer size ID: |
in |
|
21 ¼ |
|
|
|
|
E.8.1 Diverter Flowlines |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 |
OD of Flowlines: |
in |
|
18 |
Running from Diverter to: |
|
|
Overboard |
Valve types: |
|
|
Piper |
Size: |
in |
|
18 16 1/8 Bore |
Working pressure: |
psi |
|
500psi |
Control valve type (air/hydraulic/etc.): |
|
|
Hydraulic |
Remote: controlled from: |
location |
|
Rig Floor |
|
location |
|
Toolpushers office |
|
location |
|
Diverter Panel |
|
|
|
|
E.8.2 Diverter Control Panels |
|
|
|
|
|
|
|
Drillers panel |
|
|
|
Make: |
|
|
NOV-Shaffer |
Model: |
|
|
|
Location: |
|
|
Drilling station, rig floor |
Locking/unlocking control: |
yes/no |
|
No |
|
|
|
|
Remote panel |
|
|
|
Make: |
|
|
NOV-Shaffer |
Model: |
|
|
|
Location: |
|
|
Toolpushers office |
Locking/unlocking control: |
yes/no |
|
No |
|
|
|
|
E.9 SUBSEA SUPPORT SYSTEM |
|
|
|
|
|
|
|
E.9.1 Riser Tensioners |
|
|
|
|
|
|
|
Quantity: |
no. |
|
16 |
Make/type: |
|
|
NOV-Hydralift |
Capacity each Tensioner: |
lbs |
|
200,000 |
Maximum stroke: |
ft |
|
12.5 |
Wireline size: |
in |
|
2 1/2 |
Line travel: |
ft |
|
50 |
Independent air compressors: |
yes/no |
|
Yes |
Independent air drying unit: |
yes/no |
|
Yes |
|
|
|
|
E.9.2 Guideline System |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make/type: |
|
|
N/A |
Capacity each Tensioner: |
st |
|
N/A |
Maximum stroke: |
ft |
|
N/A |
Wireline size: |
in |
|
N/A |
Line travel: |
ft |
|
N/A |
Line storage drums with tensioners: |
yes/no |
|
N/A |
|
|
|
|
E.9.3 Remote Guideline Replacement Tool |
|
|
|
|
|
|
|
Make/type: |
|
|
N/A |
|
|
|
|
E.9.4 Remote Guideline Cutting Tool |
|
|
|
|
|
|
|
Make/Type: |
|
|
N/A |
|
|
|
|
E.9.5 Pod Line Tensioners |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make/type: |
|
|
N/A |
Capacity each Tensioner: |
st |
|
N/A |
Maximum stroke: |
lt |
|
N/A |
Wireline size: |
in |
|
N/A |
Line travel: |
ft |
|
N/A |
|
|
|
|
E.9.6 Tensioner/Compensator |
|
|
|
Air Pressure Vessels |
|
|
|
|
|
|
|
Quantity: |
no. |
|
52 |
Total capacity: |
ft3 |
|
58.45 | |
Rated working pressure: |
psi |
|
3,000 | |
Pressure relief valve installed: |
yes/no |
|
Yes | |
|
|
|
| |
E.10 BOP CONTROL SYSTEM |
|
|
| |
|
|
|
| |
E.10.1 Surface Accumulator Unit |
|
|
| |
(see also E.2.8 & E.4.8 - Subsea Accumulators) |
|
|
| |
|
|
|
| |
Make: |
|
|
NOV-Shaffer | |
Model/type: |
|
|
5th generation Mux | |
Location: |
|
|
Subsea Module | |
Soluble oil reservoir capacity: |
U.S.gal |
|
1500 | |
Oil/water mix capacity: |
U.S.gal/min |
|
30 | |
Glycol reservoir capacity: |
U.S. gal |
|
500 | |
No. of bottles installed: |
no. |
|
63 | |
Useful capacity per accumulator (w/o pre-charge): |
U.S.gal |
|
15 | |
Bottle working pressure: |
psi |
|
5,000 | |
Control manifold model: |
|
|
NOV-Koomey | |
Regulator type: |
|
|
| |
Total useful accumulator volume (surface and stack) equals all Preventer opening and closing volumes: |
yes/no |
|
Yes | |
|
|
|
| |
E.10.2 Accumulator Hydraulic Pumps |
|
|
| |
|
|
|
| |
Electric driven |
|
|
| |
Quantity: |
no. |
|
3 (1 x for additional redundancy) | |
Make: |
|
|
Odessa | |
Model: |
|
|
Triplex | |
Each driven by motor of power: |
hp |
|
150 (#3 135) | |
|
|
|
| |
Air driven |
|
|
| |
Quantity: |
no. |
|
N/A | |
Make: |
|
|
N/A | |
Model: |
|
|
N/A | |
Each driven by motor of power: |
hp |
|
N/A | |
Flow rate of each pump: |
U.S.gals/min |
|
N/A | |
At minimum operating pressure: |
psi |
|
N/A | |
|
|
|
| |
E.10.3 Drillers Control Panel |
|
|
| |
|
|
|
| |
Graphic control panel at Drillers position showing Subsea functions with controls for the following functions of the BOP stack |
|
|
| |
|
|
|
| |
Marine riser connector: |
yes/no |
|
Yes | |
All annular type Bops: |
yes/no |
|
Yes | |
All ram type Bops: |
yes/no |
|
Yes | |
Lock for ram type Bops : |
yes/no |
|
Yes | |
Wellhead and LMRP connector: |
yes/no |
|
Yes | |
Inner and outer kill and choke line valves: |
yes/no |
|
Yes | |
Low acc. pressure warning: |
yes/no |
|
Yes | |
Low reservoir level warning: |
yes/no |
|
Yes | |
Low rig air pressure warning: |
yes/no |
|
Yes | |
Pressure Regulator for annular: |
yes/no |
|
Yes |
Flowmeter: |
yes/no |
|
Yes |
Quantity of pressure gauges: |
no. |
|
28 |
Emergency push button for automatic riser disconnection: |
|
|
Yes |
Other control functions: |
yes/no |
|
Yes |
Control panel make: |
|
|
NOV-Shaffer |
Control panel model: |
|
|
5th generation Mux |
|
|
|
|
E.10.4 Remote Control Panels |
|
|
|
|
|
|
|
Ability to operate main closing unit valves directly: |
yes/no |
|
Yes |
Quantity: |
no. |
|
1 (Toolpushers) |
Make/model: |
|
|
NOV-Shaffer |
Locations: |
|
|
Toolpushers office |
Operating system routing (Direct/via Primary Control Panel) |
|
|
Silvertech PLC unit |
|
|
|
|
E.11 SUBSEA CONTROL SYSTEM |
|
|
|
|
|
|
|
E.11.1 Hose Reels |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 |
Location: |
|
|
Moonpool |
Make/type: |
|
|
NOV |
Maximum storage length each: |
ft |
|
11,000 |
Drive motor type: |
|
|
Air |
|
|
|
|
E.11.2 Pod Hose |
|
|
Mux Cable |
|
|
|
|
Location: |
|
|
Moonpool MUX |
Length: |
ft |
|
11,000 feet |
OD hose: |
in |
|
1.1 |
Control line ID: |
in |
|
N/A |
Quantity total: |
no. |
|
N/A |
Quantity spare (when new): |
no. |
|
N/A |
Control line ID: |
in |
|
N/A |
Quantity total: |
no |
|
N/A |
Quantity spare (when new): |
no. |
|
N/A |
Control line ID: |
in |
|
N/A |
Quantity total: |
no. |
|
N/A |
Quantity spare (when new): |
no. |
|
N/A |
|
|
|
|
E.11.3 Pod Hose Manifold |
|
|
|
|
|
|
|
Make/model: |
|
|
N/A |
Surface test stump: |
yes/no |
|
N/A |
|
|
|
|
E.11.4 Surface Test Pod |
yes/no |
|
No Pod test stand |
|
|
|
|
E.12 ACOUSTIC EMERGENCY BOP CONTROL SYSTEM |
|
|
|
|
|
|
|
Make/model: |
|
|
Kongsberg |
Type (fixed/portable): |
|
|
Both |
Number of functions: |
no. |
|
6 |
Type of functions: |
|
|
|
LMRP connector release: |
yes/no |
|
Yes |
Shear ram close: |
yes/no |
|
Yes (Blind-Shear) |
Other: |
|
|
Ram 2 close, BSR close, Retract all stabs, RC unlock |
|
|
|
|
E.13 SUBSEA AUXILIARY EQUIPMENT |
|
|
|
|
|
|
|
E.13.1 Hole Position Indicator |
|
|
|
|
|
|
|
Make/type |
|
|
Via DP system |
Quantity of monitors: |
no. |
|
N/A |
Monitor location: |
|
|
N/A |
Monitor location: |
|
|
N/A |
Recorder: |
yes/no |
|
N/A |
|
|
|
|
E.13.2 Riser Angle Indicator |
|
|
|
|
|
|
|
Make/type |
|
|
NOV-Shaffer |
Quantity of monitors: |
no. |
|
4 |
Monitor location: |
|
|
Drillers station, Toolpushers office, BOP Central Control Console and DP Operator |
Recorder: |
yes/no |
|
No |
|
|
|
|
Make/type |
|
|
|
Quantity of monitors: |
no. |
|
|
Monitor location: |
|
|
|
Recorder: |
yes/no |
|
|
|
|
|
|
E.13.3 Slope Indicators |
|
|
|
|
|
|
|
Make: |
|
|
NOV-Shaffer |
Quantity: |
no. |
|
4 |
Provision for installation on |
|
|
|
BOP: |
yes/no |
|
Yes (LMRP & BOP) |
Pin connector: |
yes/no |
|
Yes |
Other: |
|
|
|
|
|
|
|
E.13.4 Underwater TV System |
|
|
|
|
|
|
|
Make/type: |
|
|
|
Quantity of TV monitors: |
no. |
|
N/A |
Monitor location: |
|
|
|
Reels/cables for maximum water depth: |
ft |
|
N/A |
Pan/tilt unit: |
yes/no |
|
N/A |
Spare camera: |
yes/no |
|
N/A |
Spare cable: |
yes/no |
|
N/A |
|
|
|
|
E.13.5 ROV System |
|
|
|
|
|
|
|
Quantity: |
no. |
|
Port side |
Location |
|
|
Provision for installation 1 port aft & 1 stbd aft |
Make: |
|
|
N/A |
Type: |
|
|
N/A |
Monitor location: |
|
|
N/A |
Monitor location: |
|
|
N/A |
Provided by (operator, contractor): |
|
|
Operator |
Maximum water depth: |
ft |
|
N/A |
Cameras - color: |
no. |
|
N/A |
Cameras - B&W: |
no. |
|
N/A |
Manipulators |
|
|
N/A |
Quantity: |
no. |
|
N/A |
Type (specially correspondent, rate, grabber): |
|
|
N/A |
Sonar |
|
|
N/A |
Type: |
|
|
N/A |
|
|
|
|
E.14 CHOKE MANIFOLD |
|
|
|
|
|
|
|
E.14.1 Choke Manifold |
|
|
|
(for instrumentation, see H.3) |
|
|
|
|
|
|
|
Make: |
|
|
RB PipeTech Ltd. |
Minimum ID: |
in |
|
3 |
Maximum WP: |
psi |
|
15,000 |
H2S service: |
yes/no |
|
Yes |
|
|
|
|
Quantity of fixed chokes: |
no. |
|
N/A |
Make: |
|
|
N/A |
Model: |
|
|
N/A |
Size (ID): |
in |
|
N/A |
|
|
|
|
Quantity of adjustable chokes: |
no. |
|
2 |
Make: |
|
|
Masterflo |
Model: |
|
|
P25 |
Size (ID): |
in |
|
1.45 |
|
|
|
|
Quantity of power chokes: |
no. |
|
2 |
Make: |
|
|
Masterflo |
Model: |
|
|
P25 |
Size (ID): |
in |
|
1.45 |
|
|
|
|
Power choke remote control panel: |
yes/no |
|
Yes |
Make: |
|
|
Hitec |
Location |
|
|
Drillers Doghouse |
Glycol injection: |
yes/no |
|
Yes |
|
|
|
|
E.14.2 Flexible Choke & Kill Lines |
|
|
|
(Connecting riser to drilling unit) |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 |
Make/type: |
|
|
Techflow Flexibles |
ID: |
in |
|
3 |
Working pressure: |
psi |
|
15,000 |
|
|
|
|
E.15 BOP TESTING EQUIPMENT |
|
|
|
|
|
|
|
E.15.1 Hydraulic BOP Test Pump |
|
|
|
|
|
|
|
Make: |
|
|
Hydroplex |
Model/type: |
|
|
HP 550 Series |
Pressure rating: |
psi |
|
25,500 |
Chart recorder: |
yes/no |
|
Yes |
|
|
|
|
E.15.2 BOP Test Stump |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 |
Test pressure: |
psi |
|
15,000 |
Type: |
|
|
H4 |
Size: |
in |
|
18 ¾ |
Connected to deck (welded/bolted): |
|
|
1 x bolted. 1x hydraulic extend/retract |
|
|
|
|
E.16 WELLHEAD RUNNING / RETRIEVING/ |
|
|
|
TESTING TOOLS (RT/RRT/TT) |
|
|
|
|
|
|
|
Wellhead make: |
|
|
N/A |
Wellhead type: |
|
|
N/A |
Wellhead size: |
in |
|
N/A |
Pressure rating: |
psi |
|
N/A |
|
|
|
|
E.16.1 RTs for Casing Installation |
|
|
|
|
|
|
|
Mechanical RT- casing housing sizes: |
in |
|
N/A |
Hydraulic RT - casing housing sizes: |
in |
|
N/A |
Pack Off RT - casing housing sizes: |
in |
|
N/A |
Hanger RT - casing hanger sizes: |
in |
|
N/A |
Hanger RT - casing type: |
|
|
N/A |
Seal Assembly RT - casing sizes: |
in |
|
N/A |
|
|
|
|
E.16.2 RRTs for Casing Installation |
|
|
|
|
|
|
|
Seal Assembly RRT - casing sizes: |
in |
|
N/A |
Wear Bushing RRT - casing sizes: |
in |
|
N/A |
Seat Protector RRT - casing sizes: |
in |
|
N/A |
|
|
|
|
E.16.3 Miscellaneous Tools |
|
|
|
|
|
|
|
Temporary guide base RT: |
yes/no |
|
N/A |
BOP stack TT: |
yes/no |
|
N/A |
Multi-purpose TT: |
yes/no |
|
N/A |
Conductor casing jetting head: |
yes/no |
|
N/A |
Clean out tool: |
yes/no |
|
N/A |
Lock ring wellhead release tool: |
yes/no |
|
N/A |
Seal assembly torque tool: |
yes/no |
|
N/A |
Utility guide frame: |
yes/no |
|
N/A |
Guide frame adapter sizes: |
|
|
N/A |
|
|
|
|
E.16.4 Booster Lines (if Fitted) |
|
|
|
|
|
|
|
OD drill pipe: |
in |
|
N/A |
Quantity: |
no. |
|
N/A |
Connection type: |
|
|
N/A |
Grade: |
|
|
N/A |
Hang off method (sq. shoulder/doughnut): |
|
|
N/A |
|
|
|
|
E.16.5 Mini Hose Bundle For Use With |
|
|
No |
Hydraulic Running Tools |
yes/no |
|
|
|
|
|
|
Control line ID: |
in |
|
N/A |
Quantity of lines: |
no. |
|
N/A |
Control line ID: |
in |
|
N/A |
Quantity of lines: |
no. |
|
N/A |
|
|
|
|
E.16.6 Emergency BOP Recovery System |
|
|
|
|
|
|
|
Emergency BOP recovery system: |
yes/no |
|
Yes |
Make/type: |
|
|
Clamp below annular + slings rated for LMRP + BOP, total weight estimated 360 tons |
F. MUD SYSTEM/BULK SYSTEM |
|
|
| |
|
|
|
| |
F.1 HIGH PRESSURE MUD SYSTEM |
|
|
| |
|
|
|
| |
System working pressure: |
psi |
|
7,500 psi | |
System test pressure: |
psi |
|
11,250 psi proof test at construction only | |
Built to which design pressure: |
|
|
7,500 psi | |
|
|
|
| |
F.1.1 Mud Pumps |
|
|
| |
Quantity: |
no. |
|
4 | |
Make: |
|
|
NOV | |
Model: |
|
|
Model 14-P-220 | |
Type: (Triplex/Duplex): |
|
|
Triplex | |
Liner sizes available: |
in |
|
7, 6 ½, 5 ½ ceramic | |
Mud pump drive motors: |
no. |
|
2 each | |
Motor type: |
|
|
General Electric 1,100 hp AC motors (2 ea per pump) | |
Continuous power rating per motor: |
hp |
|
1,100 hp (per motor) | |
Fluid end: |
type |
|
| |
Maximum working pressure: |
psi |
|
7,500 psi | |
Test pressure: |
psi |
|
| |
Pump stroke counter: |
type |
|
Yes | |
Supercharging pump: |
type |
|
Yes (Halco 8 x 6 x 14) | |
Driven by motor of power: |
hp |
|
100 hp | |
Discharge/Suction line ID: |
in/in |
|
6 | |
M.P. Pulsation Dampener: |
type |
|
Yes | |
Reset Relief Valve: |
type |
|
NOV Titan BX | |
Working flowrate per pump at 90% of spm: |
max |
|
| |
|
in |
|
| |
Pump speed (90% of max.): |
spm |
|
105 spm | |
Pump pressure: |
psi psi |
|
4,615 (7 liner) | |
Working flowrate @ 100% volumetric output: |
U.S. gal/min |
|
735 gpm | |
|
|
|
| |
F.1.2 Transfer Pumps/Mixing Pumps |
|
|
| |
|
|
|
| |
Transfer pumps |
|
|
| |
Quantity: |
no. |
|
6 | |
Make: |
|
|
NOV Halco | |
Model: |
|
|
6 x 8 x 14 | |
Type: |
|
|
Centrifugal | |
Drive motor type: |
|
|
Electrical | |
Power output: |
hp |
|
100 Hp @ 1750 RPM | |
|
|
|
| |
Mixing pumps |
|
|
| |
Quantity: |
no. |
|
3 | |
Make: |
|
|
NOV Halco | |
Model: |
|
|
6 x 8 x 14 | |
Type: |
|
|
Centrifugal | |
Drive motor type: |
|
|
Electrical | |
Power output: |
hp |
|
125 Hp @ 1750 RPM | |
F.1.3 Booster Pump |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A (Use a main Mud Pump, with dedicated boost standpipe only in mud pump room) |
Make/type: |
|
|
N/A |
Pumping capacity (each): |
|
|
N/A |
U.S.gals/min |
|
|
|
Drive motor type: |
|
|
N/A |
Power output: |
hp |
|
N/A |
|
|
|
|
F.1.4 Standpipe Manifold |
|
|
|
|
|
|
|
Quantity of standpipes: |
no. |
|
2 ( +1 each boost standpipe in the mud pump room) |
Standpipes ID: |
in |
|
5 |
H-Type Standpipe manifold: |
yes/no |
|
Yes |
Kill line outlet: |
yes/no |
|
Yes |
Fill-up/bleed-off line outlet: |
yes/no |
|
Yes |
Outlets (total): |
no. |
|
2 |
ID: |
in |
|
3 & 2 |
Type connections: |
|
|
Weco Fig 1502 male |
Dimensions OD x ID: |
in x in |
|
3 & 2 |
Design standard: |
|
|
API |
|
|
|
|
F. 1.5 Rotary Hoses |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 |
Make/type: |
|
|
Gates Rubber |
ID x length: |
in x ft |
|
4 x 113 |
Snubbing lines: |
yes/no |
|
Yes |
|
|
|
|
F.1.6 Cementing Hose |
|
|
|
|
|
|
|
Type (coflexip, etc): |
|
|
Coflexip (+ cement standpipe) |
Length: |
ft |
|
144 |
ID: |
in |
|
3 |
Working pressure: |
psi |
|
15,000 psi |
|
|
|
|
F.1.7 Chiksan Steel Hoses |
|
|
|
|
|
|
|
Integral on-screwed: |
yes/no |
|
Welded |
Make/type |
|
|
Weco Fig 1502 |
ID: |
in |
|
2 |
Section length: |
ft |
|
8 ft |
Quantity: |
no. |
|
4 |
Section length: |
ft |
|
10 ft Swivel loops |
Quantity: |
no. |
|
5 |
ID: |
in |
|
3 |
Section length: |
ft |
|
3.5 ft |
Quantity: |
no. |
|
8 |
Section length: |
ft |
|
4 ft |
Quantity: |
no. |
|
11 |
|
|
|
|
Sweep swivels, make/type: |
|
|
Weco Fig 1502 |
Nom. size ID: |
in |
|
2 |
Quantity: |
|
|
8 |
Nom. size ID: |
in |
|
3 |
Quantity: |
|
|
16 |
Suitable for H2S service: |
yes/no |
|
Yes |
|
|
|
|
F.2 LOW PRESSURE MUD SYSTEM |
|
|
|
|
|
|
|
F.2.1 Mud Tanks |
|
|
|
|
|
|
|
Quantity: |
no. |
|
16 / 5 (active / reserve) |
Total capacity: |
bbl |
|
6,000 bbls + 9,000 bbl |
Height: |
ft |
|
9 ft |
Capacity, tank No. 1: |
bbl |
|
500 bbl |
Type (active/reserve): |
|
|
Active |
Capacity, tank No. 2: |
bbl |
|
500 bbl |
Type (active/reserve): |
|
|
Active |
Capacity, tank No. 3: |
bbl |
|
250 bbl |
Type (active/reserve): |
|
|
Active |
Capacity, tank No. 4: |
bbl |
|
250 bbl |
Type (active/reserve): |
|
|
Active |
Capacity, tank No. 5: |
bbl |
|
500 bbl |
Type (active/reserve): |
|
|
Active |
Capacity, tank No. 6: |
bbl |
|
500 bbl |
Type (active/reserve): |
|
|
Active |
Capacity, tank No. 7: |
bbl |
|
500 bbl |
Type (active/reserve): |
|
|
active |
Capacity, tank No. 8: |
bbl |
|
500 bbl |
Type (active/reserve): |
|
|
Active |
Capacity, tank No. 9: |
bbl |
|
500 bbl |
Type (active/reserve): |
|
|
Active |
Capacity, tank No. 10: |
bbl |
|
500 bbl |
Type (active/reserve): |
|
|
Active |
Capacity, tank No. 11: |
bbl |
|
500 bbl |
Type (active/reserve): |
|
|
Active |
Capacity, tank No. 12: |
bbl |
|
500 bbl |
Type (active/reserve): |
|
|
Active |
Capacity, tank Slug No. 1: |
bbl |
|
125 bbl |
Type (active/reserve): |
|
|
Active |
Capacity, tank Slug No. 2: |
bbl |
|
125 bbl |
Type (active/reserve): |
|
|
Active |
Capacity, tank Chemical No. 1: |
bbl |
|
125 bbl |
Type (active/reserve): |
|
|
Active |
Capacity, tank Chemical No. 2: |
bbl |
|
125 bbl |
Type (active/reserve): |
|
|
Active |
Capacity, tank Reserve No. 1: |
bbl |
|
1,500 bbl |
Type (active/reserve): |
|
|
Reserve |
Capacity, tank Reserve No. 2: |
bbl |
|
1,500 bbl |
Type (active/reserve): |
|
|
Reserve |
Capacity, tank Reserve No. 3: |
bbl |
|
1,500 bbl |
Type (active/reserve): |
|
|
Reserve |
Capacity, tank Reserve No. 4: |
bbl |
|
1,500 bbl |
Type (active/reserve): |
|
|
Reserve |
Capacity, tank Reserve No. 5(Reserve or Waste): |
bbl |
|
3,000 bbl |
Type (active/reserve): |
|
|
Reserve |
|
|
|
|
Capacity Sand Trap: |
bbl |
|
60 bbls |
Capacity degasser tank: |
bbl |
|
60 bbls |
Capacity Desilter Tank |
|
|
60 bbls |
Capacity Desander Tank |
|
|
60 bbls |
Capacity Return Tank |
|
|
60 bbls |
Mud agitator in each tank |
yes/no |
|
Yes (except Sand trap and Degasser) |
Mud guns in each tank: |
yes/no |
|
Yes ( except mud process tanks ) |
|
|
|
|
F.2.2 Settling Tank |
|
|
|
Quantity: |
no. |
|
2 |
Total capacity: |
bbl |
|
125 bbl ea.(chem. Tanks .see F.2.1.) |
|
|
|
|
F.2.3 Pill/Slug Tank |
|
|
|
Quantity: 2 ea. |
no. |
|
|
Capacity: |
bbl |
|
125 bbl ea. (see F.2.1.) |
Mud agitator: |
yes/no |
|
Yes |
Mud guns: |
yes/no |
|
Yes |
|
|
|
|
F.2.4 Trip Tank |
|
|
|
|
|
|
|
Capacity: |
bbl |
|
60 bbl |
Capacity/unit length: |
bbl/ft |
|
5.08 bbl/ft |
Level indicator: |
yes/no |
|
Yes |
Electric pump make: |
|
|
NOV Halco |
Number |
|
|
2 |
Model/type: |
|
|
Centrifugal 2,500 Supreme 6 x 5 x 14 |
Motor output: |
hp |
|
50 hp |
Facility for casing fill-up: |
yes/no |
|
No |
Alarm and strip chart recorder (see H.1.11): |
yes/no |
|
Yes |
|
|
|
|
F.2.5 Stripping Tank |
|
|
|
|
|
|
|
Capacity: |
bbl |
|
8 bbl |
Capacity/unit length: |
bbl/ft |
|
1.56 bbl/ft |
Equalizing facility with trip tank: |
yes/no |
|
No |
Transfer pump: |
yes/no |
|
Yes |
|
|
|
|
F.2.6 Chemical Mixing Tank |
|
|
|
Quantity: 2 ea. |
no. |
|
|
Capacity: |
bbl |
|
125 bbl ea. ( see F.2.1.) |
Chemical mixer type: |
|
|
NOV-Brandt Agitator / MA-15 |
|
|
|
|
F.2.7 Shale Shakers |
|
|
|
|
|
|
|
Primary: |
|
|
|
Quantity: |
no. |
|
7 |
Make/model: |
|
|
NOV-Thule VSM 300 with fume extraction hood Balanced |
Type: |
|
|
epiliptical motion, low profile, cascade shaker |
Driven by no. of electric motors: |
no. |
|
2 |
Design flowrate (total): |
bbl/min |
|
2000 Gpm 18 flowline (diverter housing shakers) |
Cascading |
|
|
|
Quantity: |
no. |
|
N/A (Primary shakers are cascading type) |
Make/model: |
|
|
N/A |
Type: |
|
|
N/A |
Driven by no. of electric motors: |
no. |
|
N/A |
Design flowrate (total): |
bbl/min |
|
N/A |
|
|
|
|
F.2.8 Desander/Desander |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make/model: |
|
|
NOV-Brandt 2,500 Supreme |
Type: |
|
|
Mission |
Number of cones x size: |
no. x in |
|
3 X 10 |
Centrifugal pump type: |
|
|
Mission |
Centrifugal pump size: |
in x i |
|
8 x 6 x 14 |
Driven by electric motor of: |
hp |
|
150HP |
Is pump dedicated to Desander: |
yes/no |
|
Yes |
Max. flowrate: |
bbl/min |
|
1600 gpm |
|
|
|
|
F.2.9 Desilter |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make/model: |
|
|
NOV-Brandt/ 2,500 Supreme |
Type: |
|
|
|
Number of cones x size: |
no. x in |
|
24 x 4 |
Centrifugal pump type: |
|
|
Mission |
Centrifugal pump size: |
in x in |
|
8 x 6 x 14 |
Driven by electric motor of: |
hp |
|
150 HP |
Is pump dedicated to Desilter: |
yes/no |
|
Shared with mudcleaner |
Max. flowrate: |
bbl/min |
|
1,600 gpm |
|
|
|
|
F.2.10 Mud Cleaner |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make/model: |
|
|
NOV-Thule /VSM 300 |
Type: |
|
|
VSM 300 (with Desilter and Desander cone set above) |
Number of cones x size: |
no. x in |
|
24 x 4 |
Centrifugal pump type: |
|
|
8 x 6 x 14 |
Centrifugal pump size: |
in x in |
|
Mission |
Driven by electric motor of: |
hp |
|
150 HP |
Is pump dedicated to Mud Cleaner: |
yes/no |
|
Shared with desilter |
Max. flowrate: |
gpm |
|
1,600 gpm |
|
|
|
|
F.2.11 Mud/Gas Separator (Poor Boy) |
|
|
|
|
|
|
|
Make/type: |
|
|
NOV-RB Pipetech / 3122-06 |
Gas discharge line ID: |
in |
|
12 |
Gas discharge location, primary: |
|
|
Crown |
Can discharge be tied into burner system: |
yes/no |
|
No |
Mud seal height: |
ft |
|
19 |
Calculated gas throughput: |
mmscf |
|
1000 Gpm |
F.2.12 Degasser |
|
|
|
|
|
|
|
Quantity: |
|
|
2 |
Make/type: |
|
|
NOV-Brandt / D-10 |
Centrifugal pump type: |
|
|
Centrifugal |
Centrifugal pump size: |
in x in |
|
6 x 8 x 14 |
Driven by electric motor of power: |
hp |
|
150 Hp |
Discharge line running to: |
|
|
Crown |
Vacuum pump make: |
|
|
Ingersoll-Rand |
Type: |
|
|
Single stage |
|
|
|
|
F.2.13 Mud Agitators |
|
|
|
|
|
|
|
Quantity: |
no. |
|
10 |
Make/model: |
|
|
NOV-Brandt HMA-30RG |
Driven by electric motor of: |
kw |
|
30 hp |
Located in tanks (see F.2.1 for tank numbers): |
|
|
1, 2, 5, 6, 7, 8, 9, 10, 11, 12, 3 (20 HP), 4 (5 HP) |
|
|
|
|
Quantity: |
no. |
|
4 |
Make/model: |
|
|
NOV-Brandt VMA 10 |
Driven by electric motor of: |
kw |
|
10 hp |
Located in tanks (see F.2.1 for tank numbers): |
|
|
Chemical 1& 2 and Slug 1 & 2 |
|
|
|
|
Quantity: |
no. |
|
3 |
Make/model: |
|
|
NOV-Brandt / VMA-5 |
Driven by electric motor of: |
kw |
|
5 hp |
Located in tanks (see F.2.1 for tank numbers): |
|
|
Return, Desander and Desilter Tanks |
|
|
|
|
Quantity: |
no. |
|
7 |
Make/model: |
|
|
NOV-Brandt HMA-40RG |
Driven by electric motor of: |
kw |
|
40 hp |
Located in tanks (see F.2.1 for tank numbers): |
|
|
Reserves 1,2,3 & 4 ; 2 x Res./Waste; Drain tk. |
|
|
|
|
F.2.14 Mud Centrifuge |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 |
Make/model: |
|
|
NOV-Brandt HS-3400 |
Feed pump make/model: |
|
|
N/A |
Driven by motor of power: |
hp |
|
VFD |
Capacity: |
bbl/min |
|
200 gal / min |
|
|
|
|
F.2.15 Mud Hopper |
|
|
|
|
|
|
|
Quantity: |
no. |
|
3 |
Make/model: |
|
|
NOV- Procon / Auto feed dustfree |
Feed pump make/model: |
|
|
NOV- Supreme 2500 8 x 6 x 14 |
Driven by motor of power: |
hp |
|
125 HP |
|
|
|
|
F.2.16 Mud Laboratory and Facilities |
|
|
|
|
|
|
|
Separate room: |
yes/no |
|
Yes |
Equipped with |
|
|
|
Mud balance: |
yes/no |
|
Yes |
Marsh funnel: |
yes/no |
|
Yes |
Filtration kit: |
yes/no |
|
No |
Sand content kit: |
yes/no |
|
No |
Stopwatch: |
yes/no |
|
No |
|
|
|
|
|
|
|
|
F.3 BULK SYSTEM |
|
|
|
|
|
|
|
F.3.1 Barite/Bentonite Silos |
|
|
|
|
|
|
|
Quantity: |
no. |
|
4 |
Capacity of each silo: |
lt |
|
113 m3 |
Locations: |
|
|
Midship fwd below deck |
Type weight loadcell: |
|
|
Electronic |
Manufacturer: |
|
|
Thames Side Maywood VC 3500 |
Pressure rating: |
psi |
|
65 psi 4.4 bar |
Relief valve(s) installed |
yes/no |
|
Yes |
Rock-catcher(s) installed |
|
|
Yes |
Dust-collectors installed |
|
|
Yes |
|
|
|
|
F.3.2 Cement Silos |
|
|
|
|
|
|
|
Quantity: |
no. |
|
4 |
Capacity of each silo: |
lt |
|
113 m3 |
Locations: |
|
|
Midship below deck |
Type weight loadcell: |
|
|
Electronic |
Manufacturer: |
|
|
Thames Side Maywood VC 3500 |
Pressure rating: |
psi |
|
65 psi 4.4 bar |
Relief valve(s) installed: |
yes/no |
|
Yes |
Rock-catcher(s) installed |
|
|
Yes |
Dust-collectors installed |
|
|
Yes |
Separate mud/cement loading facilitates: |
yes/no |
|
Yes |
Discharge line for cement independent from barite/bentonite discharge line: |
yes/no |
|
Yes |
|
|
|
|
F.3.3 Cement Day Tanks |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 |
Capacity of each silo: |
lt |
|
40 m3 |
Locations: |
|
|
Outside Cement Room |
Type weight loadcell: |
|
|
Electronic |
Manufacturer: |
|
|
Thames Side Maywood VC 3500 |
Pressure rating: |
psi |
|
65 psi 4.4 bar |
Relief valve(s) installed: |
yes/no |
|
Yes |
F.3.4 Surge Tank for Barite/Bentonite |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 (one each) |
Capacity of each silo: |
lt |
|
6 m3 |
Locations: |
|
|
Sackroom mixing level |
Type weight loadcell: |
|
|
Electronic |
Manufacturer: |
|
|
Thames Side Maywood VC 3500 |
Pressure rating: |
psi |
|
65 psi 4.4 bar |
Relief valve(s) installed: |
yes/no |
|
Yes |
|
|
|
|
F.3.5 Surge Tank for Cement |
|
|
Dowell-Schlumberger free placement |
|
|
|
|
Quantity: |
no. |
|
1 |
Capacity of each tank: |
lt |
|
70 cuft |
Type weight loadcell: |
|
|
Electronic |
Manufacturer: |
|
|
Thames Side Maywood VC 3500 |
Pressure rating: |
psi |
|
Non-pressurized |
Relief valve(s) installed: |
yes/no |
|
Yes |
|
|
|
|
F.3.6 Bulk Transfer System (see also C.1.8 - Compressed Air Systems) |
|
|
|
|
|
|
|
Independent air system for the silos & surge tanks consisting of a high-volume low-\pressure compressor & air dryer: |
yes/no |
|
No |
|
|
|
|
Air reduced from main air supply through pressure Regulators: |
yes/no |
|
Yes |
|
|
|
|
Separate volume tank & drier: |
yes/no |
|
Yes |
G. CASING/CEMENTING EQUIPMENT |
|
|
| |
|
|
|
| |
G.1 CASING EQUIPMENT |
|
|
| |
|
|
|
| |
G.1.1 API Casing Drifts |
|
|
| |
|
|
|
| |
For casing OD, weight, quantity: |
in/lbs/ft/no. |
|
20 | |
|
|
|
| |
For casing OD, weight, quantity: |
in/lbs/ft/no. |
|
13 3/8 | |
|
|
|
| |
For casing OD, weight, quantity: |
in/lbs/ft/no. |
|
9 5/8 | |
|
|
|
| |
For casing OD, weight, quantity: |
in/lbs/ft/no. |
|
7 | |
|
|
|
| |
G.1.2 Clamp-On Type Casing Thread Protectors |
|
|
| |
|
|
|
| |
For casing OD, quantity: |
in/no. |
|
13 3/8 / 80 for racking casing in derrick | |
For casing OD, quantity: |
in/no. |
|
9 5/8 / 105 for racking casing in derrick | |
For casing OD, quantity: |
in/no. |
|
7 / 105 for racking casing in derrick | |
For casing OD, quantity: |
in/no. |
|
| |
|
|
|
| |
G.1.3 Side Door Casing Elevator |
|
|
| |
|
|
|
| |
Quantity: |
no. |
|
2 | |
For OD casing: |
in |
|
36 | |
Make/type: |
|
|
Blohm&Voss SDS-250-6 | |
Capacity: |
st |
|
250 | |
|
|
|
| |
Quantity: |
no. |
|
2 sets of inserts (Total 5 sets of 2) | |
For OD casing: |
in |
|
20 +16 + 13 5/8 + 13 3/8 + 10 ¾ | |
Make/type: |
|
|
Blohm&Voss VES-SD-500-2 | |
Capacity: |
st |
|
500 | |
|
|
|
| |
Quantity: |
no. |
|
2 sets of inserts (Total 3 sets of 2) | |
For OD casing: |
in |
|
9 7/8 + 9 5/8 + 7 | |
Make/type: |
|
|
Blohm&Voss VES-SD-750/1000 | |
Capacity: |
st |
|
1000 | |
|
|
|
| |
Quantity: |
no. |
|
TBC | |
For OD casing: |
in |
|
| |
Make/type: |
|
|
| |
Capacity: |
st |
|
| |
|
|
|
| |
Quantity: |
no. |
|
TBC | |
For OD casing: |
in |
|
| |
Make/type: |
|
|
| |
Capacity: |
st |
|
| |
|
|
|
| |
G.1.4 Single Joint Casing Elevators |
|
|
| |
|
|
|
| |
Quantity: |
no. |
|
2 + 2 | |
For OD casing: |
in |
|
20 + 16 | |
Make/type |
|
|
Blohm&Voss | |
Safety latches: |
yes/no |
|
Yes | |
Quantity: |
no. |
|
2 + 2 |
For OD casing: |
in |
|
13 5/8 + 13 3/8 |
Make/type: |
|
|
Blohm&Voss |
Safety latches: |
yes/no |
|
Yes |
|
|
|
|
Quantity: |
no. |
|
2 |
For OD casing: |
in |
|
9 5/8 |
Make/type: |
|
|
Blohm&Voss |
Safety latches: |
yes/no |
|
Yes |
|
|
|
|
Quantity: |
no. |
|
2 |
For OD casing: |
in |
|
7 |
Make/type: |
|
|
Blohm&Voss |
Safety latches: |
yes/no |
|
Yes |
|
|
|
|
G.1.5 Slip Type Spiders |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 (inserts only) |
Make/type: |
|
|
Blohm&Voss PS 1000 |
Capacity: |
st |
|
1000 |
W/slips for OD casing sizes: |
in |
|
20, 16, 13 5/8, 13 3/8, 9 5/8, 7 |
|
|
|
|
G.1.6 Casing Slips |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Blohm&Voss / CSI |
For OD casing: |
in |
|
20 |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Blohm&Voss / CSI |
For OD casing: |
in |
|
13 3/8 |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Blohm&Voss / CSI |
For OD casing: |
in |
|
9 5/8 |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Blohm&Voss / CSI |
For OD casing: |
in |
|
7 |
|
|
|
|
G.1.7 Casing Bowls |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Blohm&Voss / 200 Ton hinged casing spider |
For OD casing (max/min): |
in/in |
|
20 |
|
|
|
|
Quantity: |
no. |
|
1+1 |
Make/type: |
|
|
NOV-Varco / CB |
For OD casing (max/min): |
in/in |
|
20 + 16 |
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Blohm&Voss / Reducing bushing for HCS-200 |
For OD casing (max/min): |
in/in |
|
13 3/8 + 9 5/8 |
Quantity: |
no. |
|
1 Set |
Make/type: |
|
|
NOV-Varco No 1 |
For OD casing (max/min): |
in/in |
|
13 3/8 |
|
|
|
|
Quantity: |
no. |
|
1 Set |
Make/type: |
|
|
NOV-Varco No 2 |
For OD casing (max/min): |
in/in |
|
9 5/8 - 10 ¾ |
|
|
|
|
G.1.8 Casing Tongs |
|
|
|
|
|
|
|
Quantity (sets): |
no. |
|
2 |
Make/type: |
|
|
Blohm&Voss / BV-100 (jaws only) |
W/jaws for OD casing (max/min): |
in/in |
|
20 + 13 3/8 |
|
|
|
|
Quantity: |
no. |
|
4 |
Make/type: |
|
|
Gear-Wrench / Petrol Beltgrip |
W/jaws for OD casing (max/min): |
in/in |
|
36 30 26 20 |
|
|
|
|
G.1.9 Power Casing Tongs |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 (insert for Hydratong iron roughneck) |
Make/type: |
|
|
NOV/FARR Hydraulic KT 7585 |
W/jaws for OD casing (max/min): |
in/in |
|
2 3/8 - 8 5/8 |
Max output torque: |
ft lbs |
|
25,000 |
Torque indicator: |
yes/no |
|
Yes |
Back-up arm: |
yes/no |
|
Yes |
|
|
|
|
Quantity: |
no. |
|
1 ((insert for Hydratong iron roughneck) |
Make/type: |
|
|
NOV/FARR Hydraulic KT 20000 |
W/jaws for OD casing (max/min): |
in/in |
|
8 5/8 - 20 |
Max output torque: |
ft lbs |
|
50,700 |
Torque indicator: |
yes/no |
|
Yes |
Back-up arm: |
yes/no |
|
Yes |
|
|
|
|
G.1.10 Power Unit for Casing & Tubing Tongs |
|
|
|
|
|
|
|
Quantity: |
no. |
|
Central HPU for NOV equipment |
Driven by electric motor: |
yes/no |
|
Yes |
|
|
|
|
G.1.11 Casing Circulating Head (Swedge) |
|
|
|
|
|
|
|
For OD casing: |
in |
|
N/A |
Connection type: |
|
|
N/A |
|
|
|
|
G.1.12 Casing Spears (Internal) |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make/type: |
|
|
|
For OD casing: |
in |
|
|
For casing weight: |
lbs/ft |
|
|
Pack-off: |
yes/no |
|
|
|
|
|
|
G.1.13 Casing Cutters (Internal) |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make/type: |
|
|
N/A |
For OD casing (max/min): |
in/in |
|
N/A |
G.1.14 Crossover to Handle Casing with DP |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
For OD casing: |
in |
|
N/A |
Casing connection: |
|
|
N/A |
Drill pipe connection type: |
|
|
N/A |
Rated capacity: |
st |
|
N/A |
|
|
|
|
G.1.15 Casing Scrapers |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make: |
|
|
N/A |
For OD casing: |
in |
|
N/A |
For casing weight: |
lbs/ft |
|
N/A |
OD body: |
in |
|
N/A |
Connection type: |
|
|
N/A |
|
|
|
|
G.2 CEMENTING EQUIPMENT |
|
|
|
|
|
|
|
G.2.1 Cement Unit |
|
|
|
|
|
|
|
Owner: |
|
|
Schlumberger |
Free placement basis: |
yes/no |
|
Yes |
Make |
|
|
Schlumberger |
Type |
|
|
CPS-665, remote control type, zone 2 |
No. of triplex pumps: |
no. |
|
2 |
Maximum working pressure: |
psi |
|
15,000 |
Maximum flowrate (total): |
bbl/min |
|
24.4 |
Unit power by (electric/diesel): |
|
|
Diesel, in sound reduction enclosure |
Recirculating mixing system: |
yes/no |
|
Yes, Mark III Slurry Chief Mixer, 8 + 16 bbls |
Capacity: |
bbl |
|
60 sxs/min, 153.6 ton/hr, 11 BBls/min, |
Motor power: |
hp |
|
1400 |
Liquid additive system: |
yes/no |
|
Yes |
Premix/batch tank: |
|
|
CBS-967, remote control type |
Quantity: |
no. |
|
2 |
Capacity (total): |
bbl |
|
200 |
Pressure recorder: |
yes/no |
|
Yes |
|
|
|
|
G.2.2 Cementing Manifold |
|
|
|
|
|
|
|
Discharge manifold working pressure: |
psi |
|
15,000 |
Cement pump discharge lines min. ID: |
in |
|
3 |
Cement pump discharge lines working pressure: |
psi |
|
15,000 (+ cement standpipe available) |
|
|
|
|
G.2.3 Cement Kelly |
|
|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Nominal size OD: |
in |
|
N/A |
Total length: |
ft |
|
N/A |
Working length: |
ft |
|
N/A |
Connection type: |
|
|
N/A |
Cement head: |
yes/no |
|
N/A |
|
|
|
|
G.2.4 Cementing Tubing |
|
|
|
|
|
|
|
Size: |
in |
|
N/A |
Length (total): |
ft |
|
N/A |
H. INSTRUMENTATION/COMMUNICATION |
|
| |
|
|
|
|
H.1 DRILLING INSTRUMENTATION AT DRILLERS POSITION |
|
Drilling Control Data Acquisition (DCDA) System Network, comprising the following inputs and displays: Machine Anticollision, Mud Pump Control incl. Resume func., Mud Pump Antisync, Mud Pump Local control panel Non-Eex, Standpipe pressure transmitter, Choke manifold pressure transmitter, Liquid mud tank levels, Liquid mud tank levels in hull, Trip tank level transmitter, guided microwave, Flow transmitter, Alarm Horn, Mud Temp In/Out, Clamp-On, Cement Pressure transmitter, Density Transmitter in Liquid mud tank, Mud pump SPM proximity switch, Rotary rpm proximity switch, Rotary torque pressure transmitter, Top Drive rpm proximity switch, Top Drive torque pressure transmitter, Hook load sensor, Block position encoder/sensor, Tong Torque Load Celle, Tong Torque Pressure Transmitter, CCTV Central, CCTV Camera NON Ex. Pan/Zoom/Tilt, CCTV Camera Eex. Zone 1 Pan/Zoom/Tilt/Auto Focus | |
|
|
|
|
H.1.1 Weight Indicator |
|
|
|
|
|
|
|
Make/type: |
|
|
NOV-HITEC |
Sensor type: |
|
|
Load pins at crown block |
Calibrated for number of lines strung (6,8,10, 12, etc): |
no. |
|
14 |
|
|
|
|
H.1.2 Standpipe Pressure Gauges |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 |
Make/type: |
|
|
NOV-Hitec- Digital with ScanSense transmitter |
Pressure range: |
psi - psi |
|
0-7,500 |
|
|
|
|
Quantity: |
no. |
|
2 |
Make/type: |
|
|
NOV/Pressure Gauge |
Pressure range: |
psi - psi |
|
0 10,000 |
|
|
|
|
Quantity: |
no. |
|
N/A |
Make/type: |
|
|
|
Pressure range: |
psi - psi |
|
|
H.1.3 Choke Manifold Pressure Gauge |
|
|
|
|
|
|
|
Quantity: |
no. |
|
4 |
Make/type: |
|
|
NOV-Hitec with transmitter |
Pressure range: |
psi - psi |
|
0 20,000 |
|
|
|
|
Quantity: |
no. |
|
4 |
Make/type: |
|
|
NOV/Pressure Gauge |
Pressure range: |
psi - psi |
|
0 20,000 |
|
|
|
|
H.1.4 Rotary Speed Tachometer |
|
|
|
|
|
|
|
Make/type: |
|
|
NOV-Hitec SDI |
|
|
|
|
H.1.5 Rotary Torque Indicator |
|
|
|
|
|
|
|
Make/type: |
|
|
NOV-Hitec SDI |
|
|
|
|
H.1.6 Motion Compensator Instruments |
|
|
|
|
|
|
|
Make/type: |
|
|
Seatex MRU H / MRU-M-MB2 |
Hook position indicator: |
yes/no |
|
Yes |
Lock/unlock indicator: |
yes/no |
|
Yes |
|
|
|
|
H.1.7 Pump Stroke Counters |
|
|
|
|
|
|
|
Make/type: |
|
|
NOV |
One pump stroke indicator and one cumulative pump stroke counter for each pump: |
yes/no |
|
Yes |
|
|
|
|
H.1.8 Tong Torque Indicator |
|
|
|
|
|
|
|
Make/type: |
|
|
NOV-Hitec SDI |
|
|
|
|
H.1.9 Pit Volume Totalizer |
|
|
|
|
|
|
|
Make/model: |
|
|
NOV-Hitec SDI VEGA |
Floats in active mud tanks: |
yes/no |
|
No (acoustic system installed) |
Floats in reserve mud tanks: |
yes/no |
|
No (acoustic system installed) |
Loss/Gain indicator: |
yes/no |
|
Yes |
Alarm (audio and visual): |
yes/no |
|
Yes |
|
|
|
|
H.1.10 Mud Flow Indicator |
|
|
|
|
|
|
|
Make/model: |
|
|
NOV-FLOX-0005H |
High/low alarm (audio and visual): |
yes/no |
|
Yes |
|
|
|
|
H.1.11 Trip Tank Indicator |
|
|
|
|
|
|
|
Make/model: |
|
|
NOV-Vega |
Chart recorder: |
yes/no |
|
Yes |
Alarm: |
yes/no |
|
Yes |
H.1.12 General Alarm System |
yes/no |
|
Yes |
|
|
|
|
H.1.13 Automatic Driller |
|
|
|
|
|
|
|
Make/type: |
|
|
Automatic ROP/WOB incorporated in Hitec control system |
|
|
|
|
H.1.14 Remote Choke Control Unit (see E.14.1) |
|
|
|
|
|
|
|
Make/model: |
|
|
NOV-Hitec |
|
|
|
|
H.2 DRILLING PARAMETER RECORDER |
|
|
|
|
|
|
|
Quantity: |
no. |
|
Provided by DCS |
Location - 1: |
|
|
Toolpusher Office |
Location - 2: |
|
|
Company Man Office |
Location 3: |
|
|
|
Make/type: |
|
|
NOV-Hitec SDI system |
Quantity of pens: |
no. |
|
N/A |
|
|
|
|
H.3 INSTRUMENTATION AT CHOKE MANIFOLD |
|
| |
|
|
|
|
H.3.1 Standpipe Pressure Gauge |
|
|
|
|
|
|
|
Make/type: |
|
|
R.B. Pipetech |
Pressure range (maximum): |
psi |
|
10,000 |
|
|
|
|
H.3.2 Choke Manifold Pressure Gauge |
|
|
|
|
|
|
|
Make/type |
|
|
R.B. Pipetech |
Pressure range (maximum) |
psi |
|
10,000 and 15,000 (fine scale) |
|
|
|
|
H.3.1 and H.3.2 combined on one panel: |
yes/no |
|
Yes |
Visible from choke operation position: |
yes/no |
|
Yes |
|
|
|
|
H.4 STANDPIPE PRESSURE GAUGE |
|
|
|
|
|
|
|
Make/type: |
|
|
SCS Nobel Elektronik / 390-B-M10 |
Pressure range: |
psi |
|
10,000 |
Visible from Drillers position: |
yes/no |
|
No |
|
|
|
|
H.5 DEVIATION EQUIPMENT |
|
|
|
|
|
|
|
H.5.1 Measuring Device |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Totco |
Deviation range: |
degree |
|
5º+ 10º |
|
|
|
|
H.5.2 Wireline Winch |
|
|
|
|
|
|
|
Make/model: |
|
|
Matthew / Surveyor II |
Wire length (nominal): |
ft |
|
35,000 |
Depth counter: |
yes/no |
|
Yes |
Wire size: |
in |
|
0.105 T-316 Stainless steel |
Pull indicator: |
|
|
Yes |
H.6 CALIBRATED PRESSURE GAUGES |
|
|
|
|
|
|
|
Make/type instrument gauges: |
|
|
N/A |
Size: |
in |
|
N/A |
Connection: |
|
|
N/A |
Range: |
psi |
|
N/A |
Quantity: |
no. |
|
N/A |
Facilities to install gauges on: |
|
|
N/A |
Standpipe manifold: |
yes/no |
|
Yes |
Choke manifold: |
yes/no |
|
Yes |
Cement unit: |
yes/no |
|
Yes |
|
|
|
|
H.7 RIG COMMUNICATION SYSTEM |
|
|
|
|
|
|
|
H.7.1 Telephone System |
|
|
|
|
|
|
|
No. of stations: |
no. |
|
109 |
Make |
|
|
CMR Korea |
Type |
|
|
IOCS-500 |
|
|
|
|
H.7.2 Public Address System |
|
|
|
|
|
|
|
Can be combined with above: |
yes/no |
|
Yes |
Make |
|
|
CMR Korea |
Type |
|
|
CPA-9000 |
Explosion proof: |
yes/no |
|
Yes in hazardous areas |
|
|
|
|
H.7.3 Drill Floor - Derrickmans Talkback |
|
|
|
|
|
|
|
No. of stations: |
no. |
|
13 |
Location: |
|
|
Drillers chair, ADs chair, ECR, crownblock, |
Make |
|
|
MRC, Bridge, Cement Unit Korea |
Type |
|
|
MTB-5002E |
Explosion proof: |
yes/no |
|
yes |
|
|
|
|
H.7.4 Hand-Held VHF Radios |
|
|
|
|
|
|
|
Quantity: |
no. |
|
5 |
Make |
|
|
Icom |
Type |
|
|
IC-GM1600 GMDSS Survival Radios |
|
|
|
|
Quantity: |
no. |
|
5 |
Make |
|
|
Icom |
Type |
|
|
ICOM IC-M88-IS Intrinsically-Safe Marine channels |
|
|
|
|
H.7.5 Hand-Held UHF Radios |
|
|
|
|
|
|
|
Quantity: |
no. |
|
12 |
Make |
|
|
Motorola |
Type |
|
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GP340 Intrinsically-Safe UHF 5 channel hand-radios |
H.8 ENVIRONMENTAL INSTRUMENTATION |
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H.8.1 Temperature Indicators |
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Air temperature: |
yes/no |
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Yes |
Make/model: |
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CMR Korea |
Sea water temperature: |
yes/no |
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Yes |
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H.8.2 Barometric Pressure Indicator |
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Make |
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(Sato) |
Type |
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(Sigma II) Barograph |
Recorder: |
yes/no |
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Yes |
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Make/model: |
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(Weems & Plath)/ Barometer |
Recorder: |
yes/no |
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No |
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H.8.3 Humidity Sensing Indicator |
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Make |
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Brannam |
Type |
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Wet Bulb |
Recorder: |
yes/no |
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No |
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H.8.4 Wave Profile Recorder |
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Make |
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N/A |
Model |
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N/A |
Recorder: |
yes/no |
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N/A |
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H.9 DP, Vessel Control and Navigation Systems |
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H.9.1 Dynamic Positioning System |
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Make |
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Kongsberg |
Type |
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DP Class 3 |
Model |
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Kongsberg (K-POS DP32) Kongsberg (K-POS DP12) Designed accord. to ABS DP-3 & DP Class 3 |
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H.9.2 PRS Position Reference Systems |
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H.9.2.1 Differential Postitioning System |
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Make |
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Kongsberg Simrad |
Typeu |
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Differential Postitioning System |
Model |
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Seatex DPS 132 |
Differential Links: |
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GPS L1/L2 built in DPS 132 |
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IALA built in DPS 132 |
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Inmarsat/SpotBeam ( demodulator Seastar 3510LR ) Location: Radio Room |
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H.9.2.2 Differential Postitioning System |
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Make |
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Kongsberg Simrad |
Type |
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Differential Postitioning System |
Model |
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Seatex DPS 4D |
Differential Links: |
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DGPS/GLONASS |
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IMU (MRU5+) |
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Inmarsat/SpotBeam ( Demodulator Seastar 3510LR ) Location: Subsea Office |
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H.9.2.3 HPR Hydroacustic Positioning System |
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Make |
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Kongsberg Simrad |
Type |
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HPR |
Model |
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2 x APOS 501 |
Transducer |
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2 x HIPAP |
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H.9.3 MRU - Motion Reference Unit |
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Make |
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Seatex MRU 5 |
Model |
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MRU-M-MB3 |
Located at |
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ECR, Port and Starboard HPR Compartment |
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H.9.4 Gyro Compass |
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Make |
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Sperry Marine |
Model |
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NAVIGAT X Mk1 |
Type |
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Digital Gyro Compass |
Located at: |
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ECR, Navigation Room x 2 |
Repeater |
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Yes, Sperry Marine,4881-AB, S/n(11381,10516,13485) Qnty-3, Nav Bridge,Bridge Wings |
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H.9.5 Wind Sensors |
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Make |
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3 x (Observer Instruments) |
Model |
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OMC-160. |
Type |
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Rotary Cup Type |
Located at: |
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Radar Mast, Derrick |
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Make |
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1 x Gill |
Model |
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Wind Observer II |
Type |
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Ultrasonic Wind Sensors |
Located at: |
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Derrick |
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H.9.6 DP Logger |
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Make |
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Kongsberg Simrad |
Model |
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Integrated Navigation System |
Type |
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H.9.7 Integration Navegation System |
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Make |
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Kongsberg Simrad |
Model |
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K-Chief |
Type |
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H.9.8 Thrusters Control System |
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Quantity |
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1 |
Make |
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Kongsberg Simrad |
Model |
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STC-400 |
Type |
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STC-400 Included Telegraph THR 4;5 and THR Emcy Stop |
IP Class |
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22 |
Location |
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K-Bridge Console |
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H.9.9 Bridge Autopilot |
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Make |
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Kongsberg |
Model |
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Type |
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H.9.10 Bridge Watch Alarm System |
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Quantity |
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1 |
Make |
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Samsung |
Model |
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WAP Bridge Watch Alarm System Included 3 Reset/Push Buttons |
Type |
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Location |
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K-Bridge Console |
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H.9.11 Gyro Monitor |
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Quantity |
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1 |
Make |
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Sperry Marine |
Model |
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NAVITWIN IV |
Type |
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0735-07 |
Location |
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K-Bridge Console |
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H.9.12 Horn Control |
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Quantity |
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1 |
Make |
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Saracom |
Model |
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HC-7123 |
Type |
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Included Auto Signal |
LOcation |
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K-Bridge Console |
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H.9.13 Planning Computer |
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Quantity |
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2 |
Make |
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Kongsberg |
Model |
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K-Bridge-PL Radar integrated |
Located at |
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Bridge chart table/K-Bridge-Console |
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H.9.14 Watch Bridge Unit |
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Quntity |
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1 |
Make |
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Konsberg |
Model |
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HA 459 000 A1 |
Type |
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Extention Alarm Panal |
Location |
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K-Bridge-Console |
H.9.15 CCTV |
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Make |
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HERNIS 34 camera system (including drawworks, iron RN fwd, IR aft, moonpool, drill floor, monkeyboard (2), shale shakers area, pipe decks fwd + aft, crown (2), helideck, thrusters rooms (6), engine rooms (3), main switchboard room (3), purifier room (2), ballast pump room, radar mast, fwd aux machinery room, welltest area (2) |
Model |
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EX286W, EX286, PT9W, PT9W&S7 |
Type |
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CCTV |
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H.9.16 Fire Detection System |
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Make |
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Autronica |
Model |
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Autro Safe-Self verify system |
Type |
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Oil&Gas |
Location |
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Nav Bridge |
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H.9.17 Doppler Sonar |
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Make |
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JRC |
Model |
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NWW-GOTB |
Type |
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JLN-550 Doppler Sonar |
Location |
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NAV Chart Desk |
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H.9.18 Echo Sounder |
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Quantity |
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1 |
Make |
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JRC |
Model |
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JFE - 680 |
Located at: |
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Bridge NAV Chart Desk |
Recorder: |
yes/no |
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Yes |
Changeover Echosounder : |
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JRC,NQE-929 |
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H.9.19 Weather Facsimile |
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Quantity |
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1 |
Make |
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JRC |
Model |
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JAX-9 B |
Located at: |
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Bridge NAV Chart Desk |
Recorder: |
yes/no |
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Yes |
Paper Code |
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6ZPT500108 |
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H.9.20 Bridge Radar |
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Quantity: |
no. |
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1 |
Make |
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Kongsberg |
Model |
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MP 7600 NAV 0575/07 |
Located at: |
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Fwd; k-Bridge-Console |
Bandwidth: |
cm |
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10 cm |
S/N |
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CZC661100GU |
Quantity: |
no. |
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1 |
Make |
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Kongsberg |
Model |
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MP7600 NAV 0575/07 |
Located at: |
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Fwd; K-Bridge-Console |
Bandwidth: |
cm |
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3 cm |
S/N |
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CZC611008Y |
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Quantity: |
no. |
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1 |
Make |
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Kongsberg |
Model |
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MP7600 NAV 0575/07 |
Located at: |
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Fwd; K-Bridge-Console |
Bandwidth: |
cm |
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3 cm |
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H.9.21 SVDR Remote Alarm Unit |
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Quantity |
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1 |
Make |
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Samsung |
Model |
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WABS |
Type |
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SVDR Remote Alarm Unit Data Voyage |
Location |
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K-Bridge-Console |
Recorder |
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Yes; NAV Instrument Room |
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H.9.22 Magnetic Compass |
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Make |
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Saracom |
Model |
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MC-180 |
Type Approval |
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Class A ISO 499 ISO 2269 |
Location |
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Heli Waiting Deck |
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H.9.23 GPS |
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Quantity |
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2 |
Make |
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JRC |
Model |
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JLR 7700MKII |
Type |
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GPS Navigator:NWZ 4570B RX NNN4331 |
Selector Switch |
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Yes, JRC NCZ-777 |
Location |
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Chart Desk Console |
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H.9.24 Course Recorder |
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Quantity |
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1 |
Make |
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EPSON |
Type |
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LQ-300II |
Model |
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P172B |
Location |
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Chart Desk Console |
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H.9.25 Speed Log Indicator |
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Make |
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JRC |
Quantity |
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1 |
Type |
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JLN-550 Doppler Sonar |
Model |
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NWW-60 TB |
Location |
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Chart Desk Console |
H.9.26 Speed Distance Indicator |
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Make |
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JRC |
Type |
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NWW-7 Distance Counter |
Location |
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K-Bridge-Console |
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H.9.27 Magnetic Compass Monitor |
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Make |
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Sperry Marine |
Type |
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0735-07 Digital |
Model |
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NAWITWIN IV |
Location |
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K-Bridge-Console |
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H.10 RADIO AND COMMS EQUIPMENT |
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Model |
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JSS-896 |
Location: |
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Radio Room and Bridge |
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H.10.1 SSB Transceiver MF/HF Radio Telephone |
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Quantity: |
no. |
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2 + 1 (GMDSS Station) |
Make |
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JRC |
Model |
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JSB-196 GM |
Facsimile capable: |
yes/no |
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Yes |
Telex capable: |
yes/no |
|
Yes |
Quantity: |
no. |
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1 |
Make/model: |
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HF Marine Transceiver IC-M710 |
Facsimile capable: |
yes/no |
|
No |
Telex capable: |
yes/no |
|
No |
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H.10.2 E.P.I.R.B. |
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Quantity: |
no. |
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1 |
Type |
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Float-Free |
Make |
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JRC |
Model |
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JQE-103 406MHz |
Location |
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Bridgewing |
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H.10.3 VHF/DSC Radio Telephone |
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Quantity: |
no. |
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3 |
Make |
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JRC |
Model |
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NCM-1770 |
Power: |
watts |
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25 / 1 |
Channels: |
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All Marine |
Location |
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Radio Room ; K-Bridge-Console- 2pcs. |
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H.10.4 UHF Radio Telephone |
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Quantity |
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3 |
Make |
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Motorola |
Model |
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GM-338 |
Located at: |
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DP Console ; Radio Room-2 |
H.10.5 VHF Radio Transceiver |
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Quantity: |
no. |
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3 |
Make |
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JRC |
Model |
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JHS-7 |
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Quantity: |
no. |
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1 |
Make |
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JRC |
Model |
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DSC VHF 32A |
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Quantity: |
no. |
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2 |
Make |
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JRC |
Model |
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DSC VHF NCH 414 |
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H.10.6 Aero Radio Beacon Transmitter |
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Quantity: |
no. |
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1 |
Make |
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Saracom |
Model |
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TS-1B |
Power: |
watts |
|
120 |
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H.10.7 Aeronautical VHF Transceiver |
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Quantity: |
no. |
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1 |
Make |
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Saracom |
Model |
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Jotron TR 810 |
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Quantity: |
no. |
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2 |
Make/model: |
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ICOM |
Model |
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IC-A24 |
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H.10.8 Watch Receiver |
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Make |
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JRC |
Model |
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JSB-196GM |
Frequency: |
kHz |
|
2182 |
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H.10.9 UAIS |
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Quantity |
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1 |
Make |
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JRC |
Model |
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JHS-182 |
Type |
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Display Unit |
Location |
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K-Bridge-Console |
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H.10.10 Radio Telex |
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Quantity |
no. |
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1 |
Make |
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JRC |
Model |
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NDZ-127J Data Terminal |
Location |
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Radio Room GMDSS Console |
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H.10.11 Satellite Communication System |
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Make |
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JRC |
Model |
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Fleet F77 JUE-410F |
Type: |
|
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A/B |
Facsimile link: |
yes/no |
|
Yes |
Telex link: |
yes/no |
|
Yes |
Telephone link: |
yes/no |
|
Yes |
Video Telephone |
|
|
Yes |
Other capabilities: |
|
|
Internet Link |
|
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|
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H.10.12 SART |
|
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Quantity |
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2 |
Make |
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JRC |
Model |
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|
JQX-30A |
Battery Expiry Date |
|
|
07/2010 |
Location |
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|
NAV Bridge Port/Stabord |
|
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|
|
Quantity |
|
|
6 Lifeboats |
|
|
|
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H.10.13 Homing Beacon Control |
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Quantity |
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1 |
Make |
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SAC |
Model |
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|
SAC Hoaming Beacon Console |
Type |
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|
|
Location |
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K-Bridge-Console |
|
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|
|
H.10.14 Distress Message Control Panel |
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|
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Quantity |
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|
1 |
Make |
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|
JRC |
Model |
|
|
NCH-321A |
Type |
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|
|
Location |
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|
K-bridge-Console |
|
|
|
|
H.10.15 Sound Reception Panel |
|
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|
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Make |
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MRC |
Model |
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MSR-9200A |
Type |
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H.10.16 Talk Back Remote Unit |
|
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|
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Make |
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|
Model |
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MRC |
Type |
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Talk Back Main |
|
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Make |
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|
Model |
|
|
CTA-9200 No: HN 1674 |
Type |
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|
|
Location |
|
|
Communication Room |
|
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|
|
H.10.17 P/A & T/B REMOTE CONTROLLER |
|
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Make |
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CMR |
Model |
|
|
|
Type |
|
|
|
P/A Main (1) (2) |
|
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|
Quantity |
|
|
2 |
Make |
|
|
|
Model |
|
|
CPA-9600-1-1 ; CPA-9600-2-1 |
General Alarm |
|
|
Yes |
Location |
|
|
Communication Room;ELE EQ. Room |
|
|
|
|
H.10.18 Bridge Telephone |
|
|
|
|
|
|
|
Make |
|
|
CMR |
Model |
|
|
|
Type |
|
|
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|
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|
H.10.19 Bridge Sound Powered Telephone |
|
|
|
|
|
|
|
Make |
|
|
CMR |
Model |
|
|
|
Type |
|
|
|
|
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|
|
H.10.20 Navtex |
|
|
|
|
|
|
|
Make |
|
|
JRC |
Model |
|
|
NCR-333 NAVTEX Receiver |
Type |
|
|
NR IS1NM518-2 |
Printer |
|
|
DPLI-414 |
|
|
|
|
H.10.21 DSC/NBDP Modem |
|
|
|
|
|
|
|
Make |
|
|
JRC |
Model |
|
|
NCT-196N |
Type |
|
|
DSC/NBDP GA17020 |
Quantity |
|
|
1 |
Location |
|
|
GMDSS console |
|
|
|
|
H.10.22 Facsimile |
|
|
|
|
|
|
|
Make |
|
|
Oki Data Corporation Thailand |
Model |
|
|
F21005B |
Quantity |
|
|
1 |
Location |
|
|
Radio Room |
|
|
|
|
H.10.23 Inmarsat-C |
|
|
|
|
|
|
|
Make |
|
|
JRC NDZ- 127C1 Data Terminal |
Model |
|
|
JUE 85 ; IME model NTF-781GM MASS |
Quantity |
|
|
1 |
Location |
|
|
GMDSS Console |
|
|
|
|
H.10.24 SSAS |
|
|
|
|
|
|
|
Make |
|
|
NEQ-3154 |
Type |
|
|
Push Button |
Quantity |
|
|
2 |
Location |
|
|
Bridge Console; Cpt. Cabin |
I. PRODUCTION TEST EQUIPMENT |
|
|
|
|
|
|
|
I.1 BURNERS |
|
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Make/type: |
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N/A (Client Third Party) |
Quantity: |
no. |
|
N/A |
Capacity: |
bbl/day |
|
N/A |
Weight: |
st |
|
N/A |
Water requirement at 100 psi: |
bbl/min |
|
N/A |
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I.2 BURNER BOOMS |
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Make/type: |
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Samsung / Swan neck |
Quantity: |
no. |
|
1 |
Length: |
ft |
|
80 ft |
Horizontal: |
yes/no |
|
Swan neck |
Height above sea level (at drilling draft): |
ft |
|
± 22m TBC |
Walkway and handrails: |
yes/no |
|
Yes |
Burner platform size: |
ft x ft |
|
TBA |
Burner mounting rotatable: |
yes/no |
|
yes |
Regulatory approvals: |
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|
ABS |
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I.3 LINES REQUIRED ON BURNER BOOMS |
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I.3.1 Oil Line |
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ID: |
in |
|
4 line |
Working pressure: |
psi |
|
1,500 psi |
Connection type at burner end: |
type |
|
TBC |
H2S: |
yes/no |
|
Yes |
Pressure gauge connection at barge end: |
in |
|
No |
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I.3.2 Gas Line |
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ID: |
in |
|
6 line |
Working pressure: |
psi |
|
1,500 psi |
Extended beyond burner by: |
ft |
|
TBC |
Connection type at burner end: |
type |
|
TBC |
H2S: |
yes/no |
|
Yes |
Pressure gauge connection at barge end: |
in |
|
No |
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I.3.3 Water Line |
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ID: |
in |
|
3 line |
Working Pressure: |
psi |
|
300 psi |
Connection type at burner end: |
type |
|
TBC |
Pressure gauge connection at barge end: |
in |
|
Yes |
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I.3.4 Air Line |
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ID: |
in |
|
4 line |
Working Pressure: |
psi |
|
150 psi |
Connection type at burner end: |
type |
|
TBC |
Pressure gauge connection at barge end: |
in |
|
No |
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I.3.5 Pilot Gasoline |
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ID: |
in |
|
1 line |
Working Pressure: |
psi |
|
150 psi |
Connection type at burner end: |
type |
|
TBC |
Pressure gauge connection at barge end: |
in |
|
No |
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I.4 SPRINKLER SYSTEM |
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Sufficient to give protection to rig and personnel against heat radiation damage from the burners: |
yes/no |
|
Yes, salt water supplied by dedicated cooling water pump in engine room |
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I.5 FIXED LINES FOR WELL TESTING |
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I.5.1 Drillfloor to Separator Area |
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Type (screwed/welded, both): |
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Welded |
Quantity: |
no. |
|
1 |
Size ID: |
in |
|
6 |
Working pressure: |
psi |
|
15,000 psi |
Connection type on drill floor: |
|
|
Clamp Nº 8 (BX 155 ring gasket) |
Connection type at separator: |
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|
TBC |
Number of valves/lines: |
no. |
|
0 |
Size of valves: |
in |
|
N/A |
H2S: |
yes/no |
|
Yes |
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I.5.2 Separator Area to Each Burner Boom |
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Type (screwed/welded, both): |
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Welded |
Quantity: |
no. |
|
1 (1 Port) |
Size ID: |
in |
|
4 Oil / 6 Gas / 4 Water / 4 Air |
Working pressure: |
psi |
|
1440 PSI |
Connection type on separator: |
type |
|
Weco 602 |
Connection type at boom: |
type |
|
Weco 602 |
Number of valves/lines: |
no. |
|
0 / 4 |
Size of valves: |
in |
|
0 |
H2S: |
yes/no |
|
Yes |
Valves installed near separator area for switching gas to either burner: |
yes/no |
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N/A (one burner boom available only, rig will weather vane) |
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I.5.3 Mud Pumps to Both Burner Booms |
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Type (screwed/welded, both): |
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N/A (Dedicated sea water cooling pump in engine room) |
Quantity: |
no. |
|
1 |
Size ID: |
in |
|
6 |
Working pressure: |
psi |
|
300 PSI |
Number of valves required: |
no. |
|
0 |
Size of valves: |
in |
|
N/A |
Connected to fire fighting pumps: |
yes/no |
|
No |
Rated line capacity at 300 psi: |
bbl/hr |
|
TBA |
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I.5.4 Rig Air System to Burners |
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Type (screwed/welded, both): |
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Welded |
Quantity: |
no. |
|
1 |
Size ID: |
in |
|
4 |
Working pressure: |
psi |
|
120 PSI |
Non-return valves fitted: |
yes/no |
|
Yes |
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I.5.5 Oil Storage Tank To Overboard |
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Type (screwed / welded, both): |
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N/A |
Quantity: |
no. |
|
N/A |
Size ID: |
in |
|
N/A |
Working pressure: |
psi |
|
N/A |
Height above water level: |
ft |
|
N/A |
Connection type at separator area: |
type |
|
N/A |
|
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I.5.6 Separator to Ventstack of Rig |
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Type (screwed/welded, both): |
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N/A |
Quantity: |
no. |
|
N/A |
Size ID: |
in |
|
N/A |
Working pressure: |
psi |
|
N/A |
Connection type at separator area: |
type |
|
N/A |
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I.6 AUXILIARY POWER AVAILABILITY |
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I.6.1 For Field Laboratory |
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Several breaker feeder:1x15 amp, 3X30 Amp, 5x50amp, 3x60 amp plus 1 220 single phase outlet and several 110 single phase outlets |
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|
|
Quantity: |
kw |
|
12 |
Volts: |
v |
|
460/480 220/120 |
Frequency: |
Hz |
|
60 hz |
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|
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I.6.2 For Crude Transfer Pump |
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Quantity: |
kw |
|
N/A |
Volts: |
v |
|
N/A |
Frequency: |
hz |
|
N/A |
|
|
|
|
I.6.3 For Electric Heaters |
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|
Well test area |
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|
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Quantity: |
no. |
|
2 |
Volts: |
v |
|
440V,1000A ; 220V ,100A |
Frequency: |
hz |
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1.6.4 For ROV |
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|
Well test area |
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Quantity: |
no. |
|
PORT & STBD |
Volts: |
v |
|
440V ( 400/250/100/20 A) |
K. ACCOMMODATIONS |
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K.1 OFFICES |
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K.1.1 Company Representatives Office |
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Quantity: |
no. |
|
3 |
Complete with desk, filing cabinets (s) and other necessary furniture: |
yes/no |
|
Yes (as per contract) |
Unrestricted view to drill floor: |
yes/no |
|
No |
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K.1.2 Contractors Representatives Office |
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Quantity: |
no. |
|
3 |
Unrestricted view to drill floor: |
yes/no |
|
1 only |
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K.1.3 Radio Room |
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Quantity: |
no. |
|
1 |
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K.1.4 Hospital Room |
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|
|
Number of beds/bunks: |
no. |
|
3 |
Wash basin: |
yes/no |
|
Yes |
Medical cabinet: |
yes/no |
|
Yes |
Dangerous drugs: |
yes/no |
|
Yes |
|
|
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|
K.2 LIVING QUARTERS |
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K.2.1 Accommodations |
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Total beds: |
no. |
|
200 |
Quantity of single bed rooms: |
no. |
|
4 |
toilets (private/shared/communal): |
|
|
Private |
Quantity of two bed rooms: |
no. |
|
71 |
toilets (private/shared/communal): |
|
|
Private |
Quantity of three bed rooms: |
no. |
|
6 |
toilets (private/shared/communal): |
|
|
Private |
Quantity of four bed rooms: |
no. |
|
9 |
toilets (private/shared/communal): |
|
|
Private |
Quantity of six bed rooms: |
no. |
|
N/A |
toilets (private/shared/communal): |
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|
N/A |
|
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K.2.2 Galley |
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Quantity: |
no. |
|
1 |
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K.2.3 Mess Seating Capacity |
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Main mess: |
no. |
|
72 seats |
Aux. mess: |
no. |
|
N/A |
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K.2.4 Conference Rooms |
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Quantity: |
no. |
|
1 |
K.2.5 Recreation Rooms |
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Quantity: |
no. |
|
1 |
Recreation facilities: |
|
|
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TV: |
no. |
|
Yes (2) + feed to each cabin |
DVD: |
no. |
|
Yes (2) + feed to each cabin |
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|
|
K.2.6 Other Rooms |
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Laundry: |
no. |
|
2 |
Dry food storage: |
no. |
|
1 |
Refrigerator: |
no. |
|
1 (4 sections + handling) |
Change rooms: |
no. |
|
1 |
Coffee Shop |
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|
1 |
Prayer room: |
no. |
|
0 |
Training Room |
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|
0 |
Gymnasium: |
no. |
|
1 (Complete with Sauna) |
L. SAFETY EQUIPMENT |
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L.1 GENERAL SAFETY EQUIPMENT |
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L.1.1 General Personnel Protective Gear |
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Safety hats |
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|
Contractor only |
(contractor only/everyone/not supplied): |
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|
|
Safety boots |
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|
Contractor only |
(contractor only/everyone/not supplied): |
|
|
|
Safety clothing |
|
|
Contractor only |
(contractor only/everyone/not supplied): |
|
|
|
Ear protection |
|
|
Everyone |
(contractor only/everyone/not supplied): |
|
|
|
Rubber gloves |
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|
Contractor only |
(contractor only/everyone/not supplied): |
|
|
|
Rubber aprons |
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|
Contractor only |
(contractor only/everyone/not supplied): |
|
|
|
Fullface visors |
|
|
Contractor only |
(contractor only/everyone/not supplied): |
|
|
|
Eye shields (for grinding machines, etc.) |
|
|
Contractor only |
(contractor only/everyone/not supplied): |
|
|
|
Dust masks: |
|
|
Contractor only |
(contractor only/everyone/not supplied): |
|
|
|
Rubber gloves (elbow length for chemical handling) |
|
|
Contractor only |
(contractor only/everyone/not supplied): |
|
|
|
Explosion proof hand torches c/w batteries |
|
|
Contractor only |
(contractor only/everyone/not supplied): |
|
|
|
Safety belts c/w lines |
|
|
Contractor only |
(contractor only/everyone/not supplied): |
|
|
|
|
|
|
|
L.1.2 Eye Wash Stations |
|
|
|
|
|
|
|
Quantity: |
no. |
|
5 |
Make/model: |
|
|
Haws / Shower and facewash |
Located at: |
|
|
Sackroom |
Located at: |
|
|
Hopper Area |
Located at: |
|
|
Shaker room |
Located at: |
|
|
Rig Floor |
Located at: |
|
|
Engine room |
|
|
|
|
Quantity: |
no. |
|
19 |
Make/model: |
|
|
Encon / Facewash station |
Located at: |
|
|
ROV area (1ea) |
Located at: |
|
|
Pipe Deck (2ea) |
Located at: |
|
|
Welding Shop (1ea) |
Located at: |
|
|
Outside BOP Control & HPU room (1 ea) |
Located at: |
|
|
Mud pit room (2ea) |
Located at: |
|
|
Aft Port Upper deck @ Old paint Locker (1 ea) |
Located at: |
|
|
Upper deck close to moonpool (2ea) |
Located at: |
|
|
C. Engine room Lower level(1ea) |
Located at: |
|
|
C. Engine Room Workshop (1 ea) |
Located at: |
|
|
P. ER Electrical Workshop Store (1 ea) |
Located at: |
|
|
P. Engine Room Oil Purifier Room (1 ea) |
Located at: |
|
|
S. Engine Room Oil treatment Room (1 ea) |
Located at: |
|
|
Shaker room (1ea) |
Located at: |
|
|
Sackroom (1ea) |
Located at: |
|
|
Outside Mud lab (1ea) |
Located at: |
|
|
Mud Pump Room (1ea) |
|
|
|
|
L.1.3 Derrick Safety Equipment |
|
|
|
|
|
|
|
Derrick escape chute (rem chute): |
no. |
|
|
Make/type: |
|
|
N/A |
Derrick safety belts: |
no. |
|
|
Make/type: |
|
|
DBI Sala / Belly Belt |
|
|
|
|
L.1.4 Derrick Climbing Assistant |
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|
|
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|
|
|
Make/type: |
|
|
Alimak (elevator) / SE-EX 450 DOL |
|
|
|
|
L.1.5 Fresh Air Blowers (Bug Blowers) |
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|
|
|
|
|
|
Quantity: |
no. |
|
N/A |
Make/type: |
|
|
N/A |
Located at: |
|
|
N/A |
|
|
|
|
L.2 GAS/FIRE/SMOKE DETECTION |
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|
|
|
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|
|
L.2.1 H2S Monitoring System |
|
|
|
|
|
|
|
Make/type: |
|
|
Konsgberg IES |
Sampling points at: |
|
|
Pump room, discharge manifold area, well test area, bell nipple, moonpool area, drill floor, drillers cabin, mud pits room, mud process room, mud pump room, BOP room, cement room, sackstore, galley and living quarters ventilation system. |
General alarm: |
yes/no |
|
|
Alarm types (audible, visual, both) at |
|
|
|
Drillers console: |
|
|
Both |
Engine room: |
|
|
Both |
Mud room: |
|
|
Both |
Living quarters each level: |
|
|
Both |
Central area each structural level: |
|
|
Both |
Pacific Bora Drilling Contract No.
Central alarm panel: |
yes/no |
|
|
Located at: |
|
|
Accomodations upper deck |
|
|
|
|
L.2.2 Combustible Gas Monitoring System |
|
|
|
|
|
|
|
Make/type: |
|
|
Detcon / PS 250 |
Sampling points at: |
|
|
|
Bellnipple: |
yes/no |
|
Yes |
Drill floor: |
yes/no |
|
Yes |
Shale shaker: |
yes/no |
|
Yes |
Mud tanks: |
yes/no |
|
Yes |
Ventilation system into living quarters: |
yes/no |
|
Yes |
Other: |
|
|
Moonpool, thruster rooms ventilation intakes, HPR room, fwd machinery room intakes, well test area, pump room ventilation intakes, engine contol room, engine room, drillers cabin air intake, welding shop, mechanical Shop, Electrcal shop, warehouse, BOP room, cement room, sack store. |
General alarm: |
yes/no |
|
|
Alarm types (audible, visual, both) at |
|
|
Both |
Drillers console: |
|
|
Yes |
Other: |
|
|
Bridge Console, ECR and around the rig |
|
|
|
|
L.2.3 H2S Detectors (Portable) |
|
|
|
Quantity: |
no. |
|
6 |
Make/type: |
|
|
MSA |
Type |
|
|
Watchman Multigas (remote with pump sensing) |
Tests |
|
|
LEL / O2 / H2S |
|
|
|
|
Quantity: |
no. |
|
4 |
Make/type: |
|
|
MSA |
Type |
|
|
Altair Multigas-4 (compact hand-held) |
Tests |
|
|
LEL / O2 / H2S / CO |
|
|
|
|
L.2.4 CO2 Gas Detectors (Portable) |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
TBA |
Phials for CO2: measuring range |
|
|
N/A |
From 20 to 200 ppm: |
no. |
|
N/A | |
From 100 tp 600 ppm: |
no. |
|
N/A | |
|
|
|
| |
L.2.5 Explosimeters |
|
|
| |
|
|
|
| |
Quantity: |
no. |
|
1 | |
Make/type: |
|
|
MSA | |
Type |
|
|
Explosimeter Model 2A | |
Tests |
|
|
Combustible Gases | |
|
|
|
| |
L.2.6 Fire/Smoke Detectors Accommodation |
|
|
| |
|
|
|
| |
Make |
|
|
Autronica | |
Model |
|
|
BS-320 | |
Fire detection: |
yes/no |
|
Yes | |
Smoke detection: |
yes/no |
|
Yes | |
Central alarm panel: |
yes/no |
|
Yes | |
Location: |
|
|
Bridge | |
|
|
|
| |
L.3 FIRE FIGHTING EQUIPMENT |
|
|
| |
|
|
|
| |
L.3.1 Fire Pumps |
|
|
| |
|
|
|
| |
Quantity: |
no. |
|
3 | |
Make/model: |
|
|
3 x Shinko KV 300 KS | |
Type: |
|
|
Three electrical driven Hyundai Motors 450 KW | |
Output (each): |
U.S.gals/min |
|
750m3/h / 130m head (each) | |
All offtake points supplied by each pump: |
yes/no |
|
Yes | |
Location of pumps: |
|
|
Port/Stbd Engine Room | |
Location of pumps: |
|
|
FWD Machinery Room Emergency Fire Pump | |
Fire fighting water delivery conforms to IMO MODU Spec: |
yes/no |
|
Yes | |
|
|
|
| |
L.3.2 Hydrants & Hoses |
|
|
| |
|
|
|
| |
Hydrants positioned such that any point may be reached by a single hose length from two separate hydrants: |
yes/no |
|
Yes | |
|
|
|
| |
Quantity of hydrants: |
no. |
|
81 exterior / 76 interior | |
Hose connections / hydrant: |
no. |
|
2 ½ exterior / 1 ½ NPT interior | |
Length: |
ft |
|
15m | |
L.3.3 Portable Fire Extinguishers |
|
|
| |
|
|
|
| |
Quantity (total): |
no. |
|
413 | |
Type 1 - CO2: |
no./lbs |
|
58 + 23 (Spare) | |
Type 2 Foam |
|
|
0 | |
Type 2 Dry Chemical: |
no./lbs |
|
199 + 133 (Spare) | |
|
|
|
| |
Mounted adjacent to access ways and escape routes: |
yes/no |
|
Yes | |
|
|
|
| |
L.3.4 Fire Blankets |
|
|
| |
|
|
|
| |
Quantity: |
no. |
|
9 | |
Type: |
|
|
Gel blanket | |
Location: |
|
|
Galley (2), Helideck (2), Welders Shop, ER Wshop, Drillers cabin, S. ER Fuel Oil Purifier Room, P ER Oil & Grease Store. | |
|
|
|
| |
L.3.5 Fixed Foam Fire-Fighting System |
|
|
| |
|
|
|
| |
Location |
|
|
Machinery Spaces | |
Approval |
|
|
N/A | |
Make/type: |
|
|
N/A | |
Quantity foam stored on site: |
gal. |
|
N/A | |
Inductor tube: |
yes/no |
|
N/A | |
Foam nozzles: |
no. |
|
N/A | |
|
|
|
| |
L.3.6 Fixed Water Fire-Fighting System |
|
|
| |
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| |
Location |
|
|
Machinery Spaces | |
Specifics |
|
|
ER P/C/S, Puri P/S, Boiler ½ | |
Approval |
|
|
ABS | |
Make |
|
|
Tanktech | |
Type |
|
|
X-Mist System | |
Required Flow |
|
|
18 m3/hr | |
Number Nozzles |
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|
7 x HL, 60 x LL | |
Conforms to |
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|
SOLAS, IMO & CLASS | |
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| |
L.3.7 Helideck Foam System |
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| |
|
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|
| |
Dedicated system adequate for at least 10 minutes fire fighting at the rate quoted in the IMO MODU code: |
yes/no |
|
Yes | |
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|
| |
Make/type: |
|
|
SKUM MONITORS | |
Quantity of monitors: |
no. |
|
3 | |
Foam type: |
|
|
AFFF 3 % | |
Rate: |
U.S.gals/min |
|
3,400 liters/min Total | |
L.3.8 Fixed Fire Extinguishing System |
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Protected spaces |
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|
Engine room, type (Halon/CO2): |
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|
CO2 |
Paint locker, type (Halon/CO2): |
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|
CO2 |
Emergency generator, type (Halon/CO2): |
|
|
CO2 |
SCR room, type (Halon/CO2): |
|
|
VFD room CO2 |
Other - location: Cargo pump room, thrusters rooms, boiler room, fwd aux. mach. room, buzz type panel rooms, engine control room, galley, switchboard rooms, purifier rooms, IGG room, drilling switch gear room and cement room. |
|
CO2 | |
Alarms (audible, visual or both): |
|
|
Both |
Automatic shutting of mechanical ventilation in protected spaces: |
yes/no |
|
Auto and Manual |
Remote manual release located at: |
|
|
Main CO2 room, aft deck |
Remote manual release located at: |
|
|
Fwd Emergency Locker |
Remote manual release located at: |
|
|
Engine Room entrance |
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|
|
|
L.3.9 Manual Water Deluge System |
yes/no |
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|
Protected spaces: |
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|
Moonpool, Drill Floor, Well Test Area Fwd and Aft B-deck. 4 Lifeboats stations Fwd upper Deck Dry Break System Heli-Fuel station |
Water supplied from fire main line: |
yes/no |
|
Yes |
|
|
|
|
L.3.10 Water Sprinkler System in Accommodation |
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| |
|
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Automatic: |
yes/no |
|
No |
Working pressure: |
psi |
|
|
Pressurized tank capacity: |
ft3 |
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|
L.4 BREATHING APPARATUS |
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L.4.1 General Sets |
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Quantity: |
no. |
|
20 sets + 20 spare cylinders |
Make: |
|
|
Draeger |
Type: |
|
|
TBC |
Bottle duration: |
min |
|
30 min |
Located at: |
qty/loc |
|
Helideck room, fwd emerg locker, rig floor, aft emerg locker, engine control room |
|
|
|
|
L.4.2 Escape Sets |
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|
Quantity: |
no. |
|
98 sets |
Make |
|
|
Draeger |
Type |
|
|
TBC |
Bottle duration: |
min |
|
10 min |
Located at: |
|
|
Aft & Fwd Emerg lockers, cranes, thrusters rooms, engine rooms, electrical workshop, ET workshop, mud logger unit, mechanical workshop, moonpool, mud lab, mud pit room, mud process room, p-tank room, rig floor, riser deck, ROV area, subsea office, warehouse, welding shop, sackroom |
|
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L.4.3 Cascade Stations |
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Quantity: |
no. |
|
N/A |
Make/type: |
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N/A |
Locations/outlets at location: |
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|
N/A |
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|
L.4.4 Breathing Air Recharge Compressor |
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|
Quantity: |
no. |
|
1 |
Make/type: |
|
|
Breathing Air Module Junior II E |
Located at: |
|
|
TBC |
|
|
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|
L.4.5 Compressed Air Breathing Apparatus Trolley Unit |
|
| |
|
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|
|
Positive pressure: |
yes/no |
|
N/A |
Make/type: |
|
|
N/A |
Air line length: |
ft |
|
N/A |
Compressed air bottles: |
|
|
N/A |
Quantity: |
no. |
|
N/A |
Size: |
ft3 |
|
N/A |
Including |
|
|
N/A |
Face mask: |
yes/no |
|
N/A |
Demand valve: |
yes/no |
|
N/A |
Microphone: |
yes/no |
|
N/A |
Safety harness: |
yes/no |
|
N/A |
Safety line (incorporating phone line) |
yes/no |
|
N/A |
L.4.6 Air Purity Test Equipment |
|
|
|
|
|
|
|
Quantity: |
no. |
|
1 |
Make |
|
|
Draeger |
Type |
|
|
Aerotest Simultan HP |
|
|
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|
L.5 EMERGENCY FIRST AID EQUIPMENT |
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L.5.1 First Aid Kits |
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|
Quantity: |
no. |
|
4 (Doctors grab bags + 1 x ECR; 1 x Dog House; 1 x Helideck) |
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|
L.5.2 Burn Kits |
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|
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|
Quantity: |
no. |
|
Nil -part of above |
|
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|
L.5.3 Resuscitators |
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|
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|
|
|
Quantity: |
no. |
|
4 (1 x Hospital) (2 x Fire teams) (1 Helideck) |
Charged (spare) oxygen cylinders: |
no. |
|
11 |
|
|
|
|
L.5.4 Stretchers |
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|
|
|
|
|
|
Quantity: |
no. |
|
2 |
Type: |
|
|
MACA Offshore (Collapsible plastic & fibReglass) |
Located at: |
|
|
Hospital & Helideck |
|
|
|
|
Quantity: |
no. |
|
3 |
Type: |
|
|
Neil Robertson (Canvas & wood) |
Located at: |
|
|
Helideck; Fire Team 1 & Fire Team 2 |
|
|
|
|
Quantity: |
no. |
|
1 |
Type: |
|
|
Aluminium Scoop |
Located at: |
|
|
Hospital |
|
|
|
|
Quantity: |
no. |
|
3 |
Type: |
|
|
Stokes Litter Metal baskets |
Located at: |
|
|
Fire Team Station 1 (2) Fire Team Station 2 (1 with floatation) |
|
|
|
|
Quantity: |
no. |
|
2 |
Type: |
|
|
Plastic Backboard stretchers with straps and head restraints |
Located at: |
|
|
Hospital |
|
|
|
|
Quantity: |
no. |
|
1 |
Type: |
|
|
Folding (aluminium & plastic) |
Located at: |
|
|
Hospital |
|
|
|
|
Quantity: |
no. |
|
1 |
Type: |
|
|
KED (Kendrick Extrication Device) |
Located at: |
|
|
Hospital |
|
|
|
|
L.6 HELIDECK RESCUE EQUIPMENT |
|
|
|
|
|
|
|
L.6.1 Storage Boxes |
|
|
|
|
|
|
|
Quantity: |
no. |
|
2 |
Construction material: |
|
|
Fiberglass |
Max. height open: |
in |
|
1 m |
|
|
|
|
L.6.2 Equipment |
|
|
|
|
|
|
|
Aircraft axe: |
yes/no |
|
Yes |
Large firemans rescue axe: |
yes/no |
|
Yes |
Crowbar: |
yes/no |
|
Yes |
Heavy duty hacksaw: |
yes/no |
|
Yes |
Spare blades: |
yes/no |
|
Yes |
Grapple hook: |
yes/no |
|
Boat Hook |
Length of wire rope attached: |
ft |
|
N/A |
Quick release knife: |
yes/no |
|
Yes |
Bolt croppers: |
yes/no |
|
Yes |
|
|
|
|
L.7 RIG SAFETY STORE |
|
|
|
|
|
|
|
Equipment to repair, recharge and restock safety equipment as listed below: |
|
|
Refer also to Section L3.3 Complete spares |
|
|
|
|
Foam concentrate: |
yes/no |
|
Yes |
Dry chemical charges: |
yes/no |
|
Yes |
CO2 charges for dry chemical extinguishers: |
yes/no |
|
Yes |
CO2 charges for water extinguishers: |
yes/no |
|
Yes |
CO2 charges for foam extinguishers: |
yes/no |
|
N/A |
Discharge hoses, control nozzles and horns & washers for DP extinguishers: |
yes/no |
|
Yes |
Fire blankets: |
yes/no |
|
Yes |
Fireproof gloves: |
yes/no |
|
Yes |
Rubber gloves - elbow length: |
yes/no |
|
Yes |
Rubber aprons: |
yes/no |
|
Yes |
Rubber boots: |
yes/no |
|
Yes |
Full face visors: |
yes/no |
|
Yes |
Eye shields (for grinding machines, etc.): |
yes/no |
|
Yes |
Dust masks: |
yes/no |
|
Yes |
Spare safety helmets, boots, overalls: |
yes/no |
|
Yes |
Gloves, hand torches, batteries, etc: |
yes/no |
|
Yes |
Spare lifebuoys: |
yes/no |
|
Yes |
Spare lifebuoy lights: |
yes/no |
|
Yes |
Fresh air blowers/inductors for ventilating enclosed spaces: |
yes/no |
|
Yes |
Spare life jackets: |
yes/no |
|
Yes |
Safety belts c/w line: |
yes/no |
|
Yes |
Full safety harnesses: |
yes/no |
|
Yes |
Spare Derrickmans safety belts: |
yes/no |
|
Yes |
Spare SCBA bottles, charged: |
yes/no |
|
Yes |
|
|
|
|
L.8 EMERGENCY WARNING ALARMS |
|
|
|
|
|
|
|
Approved system to give warning of different emergencies: |
yes/no |
|
Yes |
|
|
|
|
L.9 SURVIVAL EQUIPMENT |
|
|
|
|
|
|
|
L.9.1. Lifeboats |
|
|
|
|
|
|
|
Make |
|
|
Umoe Schat-Harding AS |
Type |
|
|
Totally-enclosed Conventional launching Gravity |
Model |
|
|
TBC |
Quantity: |
no. |
|
6 |
Capacity: |
|
|
70 persons each |
person/craft |
|
|
|
Locations (fore, aft, port, stbd): |
|
|
Port FWD x2, Stbd FWD x2, Port Aft x1, Stbd Aft x1 |
Fire protection: |
yes/no |
|
Water Spray protection |
Emergency Air |
|
|
Yes |
Fitted VHF Radio |
|
|
Yes |
SART |
|
|
Yes |
EPIRB |
|
|
Yes |
Flares: |
yes/no |
|
Yes |
Food: |
yes/no |
|
Yes |
First aid kits: |
yes/no |
|
Yes |
|
|
|
|
L.9.2 Life Rafts |
|
|
|
|
|
|
|
Make |
|
|
Viking |
Type |
|
|
25P Inflatable |
Quantity: |
no. |
|
14 (plus 4 spare) |
Capacity: |
|
|
25 |
person/craft |
|
|
|
Davit launched: |
yes/no |
|
No |
Locations (fore, aft, port, stbd): |
|
|
4xPF, 4xSF, 3xPA, 3xSA + 4xspare |
Fire protection: |
yes/no |
|
No |
Radios: |
yes/no |
|
No |
Flares: |
yes/no |
|
Yes |
Food: |
yes/no |
|
Yes |
First aid kits: |
yes/no |
|
Yes |
|
|
|
|
L.9.3 Rescue Boat |
|
|
|
|
|
|
|
Make |
|
|
Norsafe AS |
Model |
|
|
Merlin 615 |
Type |
|
|
Diesel Water-Jet FRC |
Length |
|
|
6.25m |
Capacity |
|
|
10 persons |
Engine power: |
hp |
|
164 HP |
Speed |
|
|
28kts @ 3 crew / 15kts @ 10 crew |
Range |
|
|
110 nm @ 3 crew |
|
|
|
|
L.9.4 Life Jackets |
|
|
|
|
|
|
|
Make |
|
|
TBC |
Type |
|
|
SOLAS |
Quantity: |
no. |
|
362 |
|
|
|
|
L.9.5 Life Buoys |
|
|
|
|
|
|
|
Make |
|
|
Danyang |
Type |
|
|
DY 5555 |
Quantity: |
no. |
|
14 |
|
|
|
|
L.9.6 Survival Suits |
|
|
|
|
|
|
|
Make |
|
|
Stearns |
Type |
|
|
I590C SOLAS 74 |
Quantity: |
no. |
|
172 |
|
|
|
|
L.9.7 Work Vest |
|
|
|
|
|
|
|
Make/type: |
|
|
Billy Pugh / Type V |
Quantity: |
no. |
|
20 |
|
|
|
|
L.9.8 Escape Ladders |
|
|
|
|
|
|
|
Make/type: |
|
|
Escape Ladders ( wood & rope) |
Quantity: |
no. |
|
3 |
Locations |
|
|
Accommodation C-Deck P/S, Poopdeck |
L.9.9 Distress Signals |
|
|
|
|
|
|
|
Type |
|
|
SART Transponder |
Make |
|
|
JRC JQX-30A |
Quantity: |
no. |
|
7 (1xeach L/B; 2xBridge) |
|
|
|
|
Type |
|
|
EPIRB with hydrostatic release |
Make |
|
|
JRC JQE-103 406 MHz |
Quantity: |
no. |
|
1 |
M. POLLUTION PREVENTION EQUIPMENT |
|
|
|
|
|
|
|
M.1. SEWAGE TREATMENT |
|
|
|
|
|
|
|
Make/model: |
|
|
1 xHamworthy / ST10 (fwd) |
System type: |
|
|
Vacuum / Aerobic |
Conforms to (Marpol, Annex IV, etc.): |
|
|
Yes |
|
|
|
|
Make/model: |
|
|
1 x Hamworthy / STI (aft) |
System type: |
|
|
Vacuum / Aerobic |
Conforms to (Marpol, Annex IV, etc.): |
|
|
Yes |
|
|
|
|
M.2 GARBAGE COMPACTION |
|
|
|
|
|
|
|
Quantity |
|
|
2 (1xPaper & 1xPlastic) |
Make/model: |
|
|
Tech Oil Products / Enviro-Pak Compactor 3000 |
System type: |
|
|
Pneumatic/Hydraulic |
Conforms to (Marpol Annex IV, etc.) |
|
|
Marpol |
|
|
|
|
|
|
|
|
M.3 GARBAGE DISPOSAL/GRINDER |
|
|
|
|
|
|
|
Make/model: |
|
|
Laboremus TL 5000 |
System type: |
|
|
Stand alone ships rail grinder |
Conforms to (Marpol Annex IV, etc.): |
|
|
Marpol |
|
|
|
|
Make/model: |
|
|
Loipart 51060BS |
System type: |
|
|
Electrical Grinder installed on galley sink |
Quantity |
|
|
2 |
Conforms to (Marpol Annex IV, etc.): |
|
|
Marpol |
END OF EMBEDDED FILE(S)
End of Attachment A1
The remainder of the page intentionally left blank.
ATTACHMENT A2 TO EXHIBIT A SCOPE OF WORK
Offshore Drilling Contract No. PBA 3
EQUIPMENT, SUPPLIES, MATERIAL AND SERVICES
TO BE FURNISHED BY COMPANY AND CONTRACTOR
Item |
|
DESCRIPTION |
|
Furnished by |
|
Furnished by |
|
Furnished by |
|
Furnished by |
|
Furnished by |
100 |
|
Contractors Equipment and Personnel |
|
|
|
|
|
|
|
|
|
|
101 |
|
Rig and ancillary equipment as listed in Attachment A1, |
|
X |
|
|
|
|
|
|
|
|
102 |
|
Personnel as listed in Attachment A3, Personnel to be Provided by CONTRACTOR. |
|
X |
|
|
|
|
|
|
|
|
103 |
|
Subject to the provisions of Section 7.1, extra personnel in excess of the normal complement listed in Attachment A3, if available, to fully support rig operations for both well centers, excluding Operator supplied Third Party personnel. Extra personnel must be requested in writing by COMPANY. CONTRACTOR shall provide such additional personnel as provided in Section 10.2. |
|
|
|
|
|
X |
|
|
|
|
104 |
|
Overtime beyond normal work schedule for CONTRACTORs personnel when requested by COMPANY. Overtime rates are listed in Attachment A3 |
|
|
|
|
|
X |
|
|
|
|
105 |
|
Additional cost (i.e. overtime, lodging, transport, etc.) resulting from a required evacuation of the drilling unit due to bad weather. |
|
|
|
|
|
X |
|
|
|
|
106 |
|
Subject to the provisions of Section 7.2 (H), any additional equipment or modifications to the Drilling Unit requested by COMPANY. |
|
|
|
|
|
X |
|
|
|
|
107 |
|
Spare parts required to keep CONTRACTOR equipment in good operating order. |
|
X |
|
|
|
|
|
|
|
|
108 |
|
All spare parts and third party services to keep COMPANY items in good operating order. |
|
|
|
|
|
|
|
X |
|
|
109a |
|
CONTRACTOR to maintain adequate stocks of screens for the following equipment as listed below: a. For each type of shaker listed in Attachment A1, CONTRACTOR to provide all screens with equal or larger opening size that DX-84 or equivalent. |
|
X |
|
|
|
|
|
|
|
|
109b |
|
b. Any other CONTRACTOR owned equipment as per Attachment A1 |
|
X |
|
|
|
|
|
|
|
|
Pacific Bora Drilling Contract No. PBA 3
109c |
|
c. All other shale shaker and flow line cleaner screens. |
|
|
|
|
|
X |
|
|
|
|
110 |
|
Replacement parts for all solids control equipment listed in Attachment A1, other than shaker screens as listed in Item 110 above. |
|
X |
|
|
|
|
|
|
|
|
111 |
|
CONTRACTOR will have scales installed on each bulk tank in order to weigh contents. |
|
X |
|
|
|
|
|
|
|
|
112 |
|
CONTRACTOR will have a surge tank or tanks with an air vent system that minimizes loss of bulk materials. |
|
X |
|
|
|
|
|
|
|
|
113 |
|
Drill pipe wipers for CONTRACTOR supplied drill pipe |
|
X |
|
|
|
|
|
|
|
|
114 |
|
Re-circulating trip tank with Drillers level readout. All lines coming out of the diverter housing must be downward sloping to aid in fluids draining from the diverter housing. |
|
X |
|
|
|
|
|
|
|
|
200 |
|
General |
|
|
|
|
|
|
|
|
|
|
201 |
|
Offshore drilling permit(s), licenses and clearance, including Navy Permit |
|
|
|
|
|
|
|
X |
|
|
202 |
|
All COMPANY radio equipment, including satellite communications, other than provided by CONTRACTOR |
|
|
|
|
|
|
|
X |
|
|
203 |
|
Radio permits and license for CONTRACTOR radio equipment. COMPANY will assist CONTRACTOR in obtaining these permits if required by CONTRACTOR. |
|
X |
|
|
|
|
|
|
|
|
204 |
|
Qualified technician to maintain CONTRACTOR communication equipment |
|
X |
|
|
|
|
|
|
|
|
205 |
|
Telephone calls by COMPANY on CONTRACTORs satellite telephone. Calls by COMPANYS third party personnel must be authorized, logged and signed for by the COMPANY Representative on the Drilling Unit. The original documentation must accompany invoices. |
|
|
|
|
|
X |
|
|
|
|
206 |
|
Telephone calls by CONTRACTOR on COMPANYS satellite telephone. These calls must be logged and authorized by the COMPANY Representative on the Drilling Unit. |
|
|
|
|
|
|
|
|
|
X |
207 |
|
Telephone calls by COMPANYs third party personnel on COMPANYs satellite telephone. |
|
|
|
|
|
|
|
X |
|
|
208 |
|
Meals and quarters for all CONTRACTORs and CONTRACTORs subcontractor personnel and up to and including the specified number of COMPANY and COMPANY third party personnel, as mentioned in Exhibit D, the Compensation. |
|
X |
|
|
|
|
|
|
|
|
209 |
|
Meals and quarters for COMPANY and COMPANY third party personnel, over those mentioned above at the rate specified in Exhibit D Compensation. |
|
|
|
|
|
X |
|
|
|
|
210 |
|
Rig positioning, weather forecasting, seabed survey and shallow hazard assessment services as required by COMPANY, CONTRACTOR or CONTRACTORs underwriters surveyors. |
|
|
|
|
|
|
|
X |
|
|
300 |
|
Marine and Logistics |
|
|
|
|
|
|
|
|
|
|
301 |
|
Transport for CONTRACTOR personnel, listed in Attachment A3, between Point of Origin and COMPANYs shore base. |
|
X |
|
|
|
|
|
|
|
|
302 |
|
All transport for CONTRACTOR material and equipment between point of procurement and COMPANY designated shore base. |
|
X |
|
|
|
|
|
|
|
|
303 |
|
Air transportation of CONTRACTOR and COMPANY personnel, between COMPANY shore base and Drilling Unit in the course of normal duties and storm evacuation. Company reserves the right to select alternative transportation modes in exceptional situations. |
|
|
|
|
|
|
|
X |
|
|
304 |
|
If CONTRACTOR requires a special flight to the Drilling Unit (for example for a tour by management or a prospective client), then this will be provided at COMPANYs discretion. |
|
|
|
|
|
|
|
|
|
X |
305 |
|
Standby and work / supply / towing vessel(s) as required, including fuel. Standby boat requirements shall be determined by COMPANY in conjunction with CONTRACTOR. |
|
|
|
|
|
|
|
X |
|
|
306 |
|
Replacement of supply vessel mooring lines initially supplied by CONTRACTOR and damaged during course of COMPANY well. |
|
|
|
|
|
X |
|
|
|
|
307 |
|
Replacement of loading and unloading hoses on board Drilling Unit initially supplied by CONTRACTOR and damaged during course of COMPANY well. |
|
|
|
|
|
X |
|
|
|
|
308 |
|
Loading and unloading services at dock site or heliport of all material and equipment of CONTRACTOR and COMPANY. |
|
|
|
|
|
|
|
X |
|
|
309 |
|
Shore base with quay site for loading out CONTRACTOR equipment. |
|
|
|
|
|
|
|
X |
|
|
310a |
|
Certified cargo baskets and slings for quay site loading out CONTRACTOR equipment. |
|
X |
|
|
|
|
|
|
|
|
310b |
|
Cargo baskets for use in transporting COMPANYs supplies on supply vessels. The baskets must be fit for purpose, marked with load rating and equipped with suitable lifting certified slings and baskets. |
|
|
|
|
|
|
|
X |
|
|
311a |
|
Wire rope certified slings for pre-slinging of CONTRACTOR furnished drill pipe and drill collars. |
|
X |
|
|
|
|
|
|
|
|
311b |
|
Wire rope certified slings for pre-slinging of COMPANY furnished drill string |
|
|
|
|
|
|
|
X |
|
|
312 |
|
Replacement of metal slings damaged during loading or unloading of CONTRACTOR furnished drill pipe and drill collars |
|
X |
|
|
|
|
|
|
|
|
313 |
|
Adequate open storage for CONTRACTOR equipment and spare parts at COMPANY shore base while equipment is in transit to rig |
|
|
|
|
|
X |
|
|
|
|
314 |
|
Transfer of CONTRACTOR equipment and spare parts between COMPANY shore base and quay |
|
|
|
|
|
|
|
X |
|
|
315 |
|
Transfer of CONTRACTOR equipment and spare parts between COMPANY shore base and CONTRACTORs third party locations. |
|
X |
|
|
|
|
|
|
|
|
316 |
|
Office for CONTRACTOR shore-based supervisory staff (three people maximum) |
|
|
|
|
|
|
|
X |
|
|
317 |
|
Office furniture and supplies for CONTRACTOR shore-based supervisory staff, subject to COMPANY approval |
|
|
|
|
|
|
|
X |
|
|
318 |
|
Transportation of CONTRACTOR Equipment During Downtime |
|
|
|
|
|
|
|
X |
|
|
319 |
|
Transportation for Medical Treatment (including Emergency Evacuation) of CONTRACTORs Personnel to Conakry clinic. |
|
|
|
|
|
|
|
X |
|
|
320 |
|
Costs Relative to Emergency Evacuation of the Drilling Unit. - reimbursed to CONTRACTOR from COMPANY |
|
|
|
|
|
X |
|
|
|
|
321 |
|
Additional CONTRACTORs Personnel requested by COMPANY Air Transportation from Point of Origin and back |
|
|
|
|
|
X |
|
|
|
|
400 |
|
Drilling Equipment & Services |
|
|
|
|
|
|
|
|
|
|
401 |
|
Cementing unit rental |
|
|
|
|
|
|
|
X |
|
|
402 |
|
All cementing services (other than the Cementing Unit) and equipment in excess of the listed in Attachment A1 |
|
|
|
|
|
|
|
X |
|
|
403 |
|
All cement and additives |
|
|
|
|
|
|
|
X |
|
|
404 |
|
Mud engineering services (but CONTRACTOR will carry out routine mud testing and treatment as required) |
|
|
|
|
|
|
|
X |
|
|
405 |
|
All drilling fluids and additives, including pallets if applicable |
|
|
|
|
|
|
|
X |
|
|
406 |
|
Mud logging service |
|
|
|
|
|
|
|
X |
|
|
407 |
|
All electric well logging services and equipment, including string shot and back-off equipment. Installation and removal of equipment. |
|
|
|
|
|
|
|
X |
|
|
408 |
|
Wireline formation testing, side wall sampling, hydraulic fracturing and acidizing. |
|
|
|
|
|
|
|
X |
|
|
409 |
|
Suitable space, as available, for installation of well logging and mud logging units, mud lab and wireline workshop. |
|
X |
|
|
|
|
|
|
|
|
410 |
|
Fishing tools for all equipment except CONTRACTOR furnished drill pipe, drill collars and downhole tools as shown in Attachment A1. |
|
|
|
|
|
|
|
X |
|
|
411 |
|
Fishing tools for all CONTRACTOR drill pipe, drill collars, and downhole tools as Attachment A1 |
|
X |
|
|
|
|
|
|
|
|
412 |
|
Repair and / or replacement parts for CONTRACTOR provided fishing tools. |
|
|
|
|
|
X |
|
|
|
|
413 |
|
Welding services required on COMPANYs equipment to the extent available from CONTRACTORs labor. |
|
X |
|
|
|
|
|
|
|
|
414 |
|
Welding materials used on COMPANYs equipment |
|
|
|
|
|
X |
|
|
|
|
415 |
|
Any geological or petroleum engineering services |
|
|
|
|
|
|
|
X |
|
|
416 |
|
ROV or diving services, if required for maintenance or repair of CONTRACTORs vessel, unless damages caused by COMPANY third party. |
|
X |
|
|
|
|
|
|
|
|
417 |
|
ROV or diving services, if required for work related to COMPANYs well or subsea facilities |
|
|
|
|
|
|
|
X |
|
|
418 |
|
Extra labor or casing crews for running casing or tubing |
|
|
|
|
|
|
|
X |
|
|
419 |
|
Directional drilling engineering services and special equipment |
|
|
|
|
|
|
|
X |
|
|
420 |
|
Jetting tools for setting 36 and 30 conductor casing |
|
|
|
|
|
|
|
X |
|
|
421 |
|
Well test unit and associated equipment for production testing including services and including a separate air compressor for any compressed air needed such equipment, where they are not listed in Attachment A1. |
|
|
|
|
|
|
|
X |
|
|
422 |
|
Drilling bits, mills (other than those listed in Attachment 1 for fishing), hole openers, reamers, under-reamers, casing scrapers, drilling bumper subs, shock subs, drilling safety joints, hydraulic drilling jars and similar downhole equipment, including replacement parts |
|
|
|
|
|
|
|
X |
|
|
423 |
|
Drill stem testing equipment if required |
|
|
|
|
|
|
|
X |
|
|
424 |
|
Handling tools, subs, etc. required for COMPANY supplied drill pipe |
|
|
|
|
|
|
|
X |
|
|
425a |
|
Initial inspection of CONTRACTORs riser, drill collars, HWDP, drill pipe, subs, pups, hoisting equipment and handling tools prior to spud of first well |
|
X |
|
|
|
|
|
|
|
|
425b |
|
Subsequent inspections of CONTRACTORs riser, drill collars, HWDP, drill pipe, subs, pups, hoisting equipment and handling tools during Contract duration and at the end of Contract |
|
|
|
|
|
X |
|
|
|
|
425c |
|
Additional COMPANY requirements during inspections described in 425a in excess of CONTRACTORs standards |
|
|
|
|
|
X |
|
|
|
|
425d |
|
Inspection of COMPANYs riser, drill collars, HWDP, drill pipe, subs, pups, hoisting equipment and handling tools prior to spud of first well. |
|
|
|
|
|
|
|
X |
|
|
426 |
|
Core barrel and core bits |
|
|
|
|
|
|
|
X |
|
|
427 |
|
All third party services pertaining to the drilling, workover, and completion operations. |
|
|
|
|
|
|
|
X |
|
|
428 |
|
Any drill pipe, HWDP, drill collars, subs, bits, reamers, hole openers, stabilizers, shock subs, and other downhole tools in excess of those provided by CONTRACTOR as shown in Attachment A1. |
|
|
|
|
|
|
|
X |
|
|
429 |
|
Drill pipe floats for CONTRACTOR supplied drill strings as shown in Attachment A1. |
|
X |
|
|
|
|
|
|
|
|
430 |
|
Drill pipe floats for COMPANY supplied drill strings |
|
|
|
|
|
|
|
X |
|
|
431a |
|
Mud pump liners - sizes 6 and 5.5 |
|
X |
|
|
|
|
|
|
|
|
431b |
|
Mud pump liners - other sizes not mentioned in 431a |
|
|
|
|
|
X |
|
|
|
|
500 |
|
BOP and Wellhead Equipment |
|
|
|
|
|
|
|
|
|
|
501 |
|
BOP fluid |
|
X |
|
|
|
|
|
|
|
|
502 |
|
Initial set rubber goods for BOP stack as per CONTRACTORs specification |
|
X |
|
|
|
|
|
|
|
|
503 |
|
All ring gaskets between sub-sea wellhead or tree and BOP Stack. |
|
|
|
|
|
|
|
X |
|
|
504 |
|
Replacement rubber goods and ring gaskets, flexjoint rubbers, riser string seals, including VBR packers, annular elements and diverter packers, for BOP stacks. Rubber goods to be compatible for use with OBM. |
|
|
|
|
|
X |
|
|
|
|
505 |
|
New annular preventer and VBR elements, choke, kill and boost line and mud gaskets required at start of Contract. CONTRACTOR to keep spare annular preventer elements as mutually agreed on board the Drilling Unit at all times. |
|
X |
|
|
|
|
|
|
|
|
506 |
|
Replacement annular elements during Contract duration and at the end of Contract |
|
|
|
|
|
X |
|
|
|
|
507 |
|
Repair / Replacement / Inspection / Transportation / Commissioning of CONTRACTOR subsea well control equipment due to abnormal wear and tear such as key seating with documentation of initial condition and end condition and proven cause of damage. |
|
|
|
|
|
X |
|
|
|
|
508 |
|
Replacement door seals for CONTRACTOR supplied BOPs when changed at COMPANYs request. |
|
|
|
|
|
X |
|
|
|
|
509 |
|
Provide equipment to do BOP test independently, as described in Attachment A1. |
|
X |
|
|
|
|
|
|
|
|
510 |
|
All wellhead and subsea equipment i.e., subsea well heads, hangers, pack offs, Christmas trees, corrosion caps, etc. |
|
|
|
|
|
|
|
X |
|
|
511 |
|
Running and retrieving tools for the following: LPWH, HPWH, casing hangers, pack-offs, wear bushings, and nominal seat protectors. |
|
|
|
|
|
|
|
X |
|
|
512 |
|
Subsea BOP test plugs, both insulation type and sealing inside the casing hanger. |
|
|
|
|
|
|
|
X |
|
|
600 |
|
Well Equipment & Supplies |
|
|
|
|
|
|
|
|
|
|
601 |
|
Fuel for all CONTRACTORs equipment on the Drilling Unit (after contract commencement) |
|
|
|
|
|
|
|
X |
|
|
602 |
|
Helicopter Fuel |
|
|
|
|
|
|
|
X |
|
|
603 |
|
An inventory of fuel is to be taken as the rig goes on and off Contract, and signed for by the COMPANYs Representative. Any balance will be reimbursed to the CONTRACTOR (if negative) or deducted from invoices (if positive) at CONTRACTORS documented invoiced cost. |
|
|
|
|
|
X |
|
|
|
|
604a |
|
Lubricants for CONTRACTOR equipment |
|
X |
|
|
|
|
|
|
|
|
604b |
|
Lubricants for Drill String (both CONTRACTOR and COMPANY provided) |
|
X |
|
|
|
|
|
|
|
|
604c |
|
Lubricants for Casing and COMPANY provided equipment |
|
|
|
|
|
|
|
X |
|
|
605 |
|
The following items, including all consumable items used therewith: |
|
|
|
|
|
|
|
X |
|
|
606 |
|
Potable water for use on board the Drilling Unit, to the extent of the capacity of the Drilling Units water makers as per Attachment A1. |
|
X |
|
|
|
|
|
|
|
|
607 |
|
Any potable water required in excess of the capacity of the Drilling Units water makers and any drill water above that provided by surplus potable water. |
|
|
|
|
|
|
|
X |
|
|
608 |
|
Any fabrication material (e.g. steel, cable) provided by CONTRACTOR to assist in rig up of COMPANY third party equipment. |
|
|
|
|
|
X |
|
|
|
|
609 |
|
All rope, cargo slings (for use by CONTRACTOR on rig), hand tools and general rig consumables. |
|
X |
|
|
|
|
|
|
|
|
700 |
|
Waste |
|
|
|
|
|
|
|
|
|
|
701 |
|
Trash compactor and bags for CONTRACTOR waste. |
|
X |
|
|
|
|
|
|
|
|
702a |
|
Disposal of CONTRACTORs Victual waste, if required by 33 CFR 151, garbage, refuse, and other non-hazardous waste, in CONTRACTOR furnished containers. |
|
X |
|
|
|
|
|
|
|
|
702b |
|
Disposal of COMPANYs and COMPANYs other contractors Victual water, if required by 33 CFR 151, garbage, refuse and other waster, in COMPANY furnished containers. |
|
|
|
|
|
X |
|
|
|
|
703a |
|
Disposal of CONTRACTORs scrap metal, drill lines, drums and other containers that have been emptied, drained and interior cleaned with water or other cleaning agents. |
|
|
|
|
|
X |
|
|
|
|
703b |
|
Disposal of COMPANYs scrap metal, drums and other containers that have been emptied, drained and interior cleaned with water or other cleaning agents. |
|
|
|
|
|
X |
|
|
|
|
704 |
|
Disposal of CONTRACTORs waste oil, waste paint, and other hazardous waste generated by CONTRACTORs Drilling Unit, equipment or personnel, or CONTRACTORs subcontractor personnel and / or equipment during the term of the Contract. Containers to be provided by CONTRACTOR. |
|
|
|
|
|
X |
|
|
|
|
705 |
|
Disposal of COMPANYs waste oil, waste paint, and other hazardous waste generated by COMPANYs or COMPANYs other contractors personnel and / or equipment during the term of the Contract. Containers to be provided by COMPANY. |
|
|
|
|
|
|
|
X |
|
|
800 |
|
Safety |
|
|
|
|
|
|
|
|
|
|
801a |
|
All safety equipment for CONTRACTOR personnel, including self-contained breathing apparatus for emergency work in H2S environments as shown in Attachment A1. |
|
X |
|
|
|
|
|
|
|
|
801b |
|
Self-contained breathing apparatus for work in H2S environment in excess of that furnished by CONTRACTOR as shown in Attachment A1 and / or cascade breathing system. |
|
|
|
|
|
|
|
X |
|
|
802 |
|
Safety equipment (e.g. floats, life belts, work vests, PPE, fire extinguishers, etc.) for the total complement on board the Drilling Unit. CONTRACTOR shall not be required to provide normal work boots, hard hats, coveralls, gloves and safety glasses to non-CONTRACTOR personnel. |
|
X |
|
|
|
|
|
|
|
|
803 |
|
Explosion-proof wiring, safety lanyards, and lighting for the Drilling Unit as required by regulations. |
|
X |
|
|
|
|
|
|
|
|
804 |
|
All COMPANYs or its other contractors equipment, materials or supplies to be brought on board the Drilling Unit shall be provided with slings properly certified for the load. |
|
|
|
|
|
|
|
X |
|
|
805 |
|
All COMPANYs or its other contractors equipment to be brought on board the Drilling Unit shall be properly inspected and certified as appropriate, including certifications of pressure vessels, prior to being placed in service on board the Drilling Unit. |
|
|
|
|
|
|
|
X |
|
|
806 |
|
COMPANY or its other contractors shall provide MSDS with all chemicals that COMPANY or its other contractors bring on board the Drilling Unit. |
|
|
|
|
|
|
|
X |
|
|
End of Attachment A2
The remainder of the page intentionally left blank.
ATTACHMENT A3 TO EXHIBIT A SCOPE OF WORK
Offshore Drilling Contract No. PBA 3
PERSONNEL TO BE FURNISHED BY CONTRACTOR
1. Number and Classification of Contractors Personnel, as per section 6.1 and Personnel Rates as per Section 1.1, Personnel Rates definition: Shown in table below.
2. Key Personnel shall be identified by Contractor and agreed to by Company a minimum of thirty days prior to the Commencement Date of the Contract.
The remainder of the page intentionally left blank.
Pacific Bora Drilling Contract No. PBA 3
3. Contractor Personnel Headcount and Daily Rate Table
|
|
|
|
NUMBER |
|
Shift Schedule |
|
Unit Rate | ||||
Key |
|
POSITION |
|
ASSIGNED |
|
ON RIG |
|
On |
|
Off |
|
Per day |
K |
|
Drilling Superintendent* |
|
2 |
|
1 |
|
6 |
|
18 |
|
2,043 |
|
|
Sr Toolpusher |
|
2 |
|
1 |
|
6 |
|
18 |
|
1,856 |
|
|
Toolpusher |
|
2 |
|
1 |
|
6 |
|
18 |
|
1,712 |
|
|
Driller |
|
4 |
|
2 |
|
12 |
|
12 |
|
1,582 |
|
|
Assistant Driller |
|
8 |
|
4 |
|
12 |
|
12 |
|
1,248 |
|
|
Mud System Operator |
|
4 |
|
2 |
|
12 |
|
12 |
|
971 |
|
|
Pumphand |
|
4 |
|
2 |
|
12 |
|
12 |
|
816 |
|
|
Floorhand |
|
16 |
|
8 |
|
12 |
|
12 |
|
764 |
|
|
Crane Operator |
|
8 |
|
4 |
|
12 |
|
12 |
|
971 |
|
|
Roustabout |
|
24 |
|
12 |
|
12 |
|
12 |
|
715 |
|
|
Quality & Training Advisor |
|
4 |
|
2 |
|
6 |
|
18 |
|
1,113 |
K |
|
Technical Superintendent* |
|
2 |
|
1 |
|
6 |
|
18 |
|
2,043 |
|
|
Planner / Scheduler |
|
2 |
|
1 |
|
6 |
|
18 |
|
1,113 |
|
|
Electrical / Electronic Supvr |
|
2 |
|
1 |
|
6 |
|
18 |
|
1,582 |
|
|
IT Specialist |
|
2 |
|
1 |
|
6 |
|
18 |
|
1,430 |
|
|
Chief Electronic Tech |
|
2 |
|
1 |
|
6 |
|
18 |
|
1,452 |
|
|
Electronic Tech |
|
4 |
|
2 |
|
6 |
|
18 |
|
1,201 |
|
|
Electrician |
|
2 |
|
1 |
|
6 |
|
18 |
|
1,430 |
|
|
Assistant Electrician |
|
4 |
|
2 |
|
12 |
|
12 |
|
1,201 |
|
|
Mechanical Supvr |
|
2 |
|
1 |
|
6 |
|
18 |
|
1,582 |
|
|
Mechanic |
|
4 |
|
2 |
|
12 |
|
12 |
|
1,430 |
|
|
Assistant Mechanic |
|
4 |
|
2 |
|
6 |
|
18 |
|
1,201 |
|
|
1st Engineer |
|
2 |
|
1 |
|
6 |
|
18 |
|
1,448 |
|
|
2nd Engineer |
|
4 |
|
2 |
|
12 |
|
12 |
|
1,201 |
|
|
3rd Engineer |
|
4 |
|
2 |
|
6 |
|
18 |
|
953 |
|
|
Motorman |
|
4 |
|
2 |
|
12 |
|
12 |
|
756 |
|
|
Sr Subsea Engineer |
|
2 |
|
1 |
|
6 |
|
18 |
|
1,885 |
|
|
Subsea Engineer |
|
2 |
|
1 |
|
18 |
|
6 |
|
1,698 |
|
|
Assistant Subsea |
|
4 |
|
2 |
|
12 |
|
12 |
|
1,219 |
|
|
Materials Coordinator |
|
2 |
|
1 |
|
6 |
|
18 |
|
1,160 |
|
|
Assistant Materials Coordinator |
|
4 |
|
2 |
|
18 |
|
6 |
|
981 |
|
|
Welder |
|
2 |
|
1 |
|
6 |
|
18 |
|
971 |
K |
|
Master* |
|
2 |
|
1 |
|
12 |
|
12 |
|
2,043 |
|
|
Chief Mate |
|
2 |
|
1 |
|
12 |
|
12 |
|
1,849 |
|
|
Sr Dynamic Pos Operator |
|
2 |
|
1 |
|
6 |
|
18 |
|
1,545 |
|
|
Dynamic Pos Operator |
|
4 |
|
2 |
|
12 |
|
12 |
|
1,230 |
|
|
Assistant Dynamic Pos Operator |
|
2 |
|
1 |
|
18 |
|
6 |
|
1,055 |
|
|
Able Bodied Seaman |
|
6 |
|
3 |
|
12 |
|
12 |
|
769 |
|
|
Radio Operator |
|
4 |
|
2 |
|
6 |
|
18 |
|
861 |
|
|
Medic |
|
2 |
|
1 |
|
6 |
|
18 |
|
1,052 |
|
|
Bosun |
|
2 |
|
1 |
|
6 |
|
18 |
|
951 |
|
|
Total on RIG (Excluding Catering) |
|
164 |
|
82 |
|
|
|
|
|
|
(K = indicate Key PERSONNEL)
(* = indicate member of Vessel Management Team VMT)
Notes for Attachment A3 Table above:
· The figures in column Unit Rate are to be used as the basis for adding personnel to the permanent crew and for determining the credit for crew members short. This includes all Training, Transportation and Catering costs.
· It is understood from time to time that there may be a shortfall in certain positions that Contractor makes up for by overtime in equivalent positions or (e.g. Floorhand staying over to work in a roustabout position) as reflected in the daily drilling report (IADC report). Any downsizing of the crew requested by Company shall be documented in writing to Contractor and is subject to Contractors approval, which may not be unreasonably withheld.
· Offshore training activities within regular working hours required by Company are considered inclusive in the Base Labor rates outlined in Unit Rate.
· For training, office work and other onshore activities required by Company, Company shall compensate Contractor the rate specified in Unit Rate for every Contractor employee required to participate in the activity.
3. The positions denoted with a K in the first column are to be fluent in English as per Section 6.1 (A) (6) and for the purposes of this Contract are designated as Key Personnel which may not be replaced or substituted without prior Company approval, which shall not unreasonably be withheld.
4. The Contractor shall provide all necessary shorebased administration and management support to fulfill its obligations under this Contract. In particular the Contractor shall provide a Rig Manager who shall be assigned to the services/operations covered hereunder and be provided on a dedicated basis prior to the Commencement Date and covering the initial Services including the Mobilization of the Drilling Unit to Companys first well location. The Rig Manager shall liaise with Companys other contractors and suppliers (e.g., for the provision of Subsea equipment, ROV, mudlogging, Wireline, etc.), participate in onshore and offshore meetings regarding the initial installation of third party equipment and plan and coordinate Contractors activities leading up to and including the Mobilization of the Drilling Unit.
5. Contractors Additional Personnel, as per Section 6.1(A)(4):
Yes: o No: x If Yes, indicate positions below:
6. Contractor will provide the following additional personnel as and when required for Contractors need, at Contractors cost;
Catering crew (8-20 persons, depending on total rig personnel on board compliment), service engineers for Contractors equipment, medic, paint crews, auditors, flag and class inspectors, trainers, and other subcontractors as required.
7. Offshore Contractor Personnel Qualifications:
a. The following offshore positions would be expected to be filled by staff with a minimum of five (5) years experience on Floating drilling units and who are fluent in conversational English and who are accomplished in reading and writing English:
i. |
|
Drilling Superintendent, Technical Superintendent, Master |
|
|
|
ii. |
|
Senior Toolpusher, Toolpusher, Driller, Assistant Driller |
|
|
|
iii. |
|
Chief Mate, Sr DPO, DPO |
|
|
|
iv. |
|
Mechanical supervisor, Electrical/Electronic supervisor |
|
|
|
v. |
|
QTA |
b. All other positions shall be filled by staff who have had previous offshore drilling experience. Contractor shall provide Company with resumes of all Key Personnel to be assigned to the project. Company reserves the right to reject Contractors proposed personnel.
Minimum Rig Personnel Qualifications Expected By Company:
i. |
|
Drilling Superintendent |
(0) |
(12) |
(13) |
(14) |
(16) |
|
|
|
|
|
|
|
|
ii. |
|
Senior Toolpusher |
(1) |
(12) |
(13) |
(14) |
(16) |
|
|
|
|
|
|
|
|
iii. |
|
Toolpusher |
(2) |
(12) |
(13) |
(14) |
(16) |
iv. |
|
Driller |
(3) |
(12) |
(13) |
(14) |
(16) |
|
|
|
|
|
|
|
|
v. |
|
Assistant Driller |
(4) |
(12) |
(13) |
(14) |
(16) |
|
|
|
|
|
|
|
|
vi. |
|
Mechanical Supervisor |
(5) |
(14) |
(16) |
|
|
|
|
|
|
|
|
|
|
vii. |
|
Electrical Supervisor |
(6) |
(14) |
(16) |
|
|
|
|
|
|
|
|
|
|
viii. |
|
Crane Operator |
(7) |
(14) |
(16) |
|
|
|
|
|
|
|
|
|
|
ix. |
|
Master |
(8) |
(14) |
(15) |
(16) |
(17) |
|
|
|
|
|
|
|
|
x. |
|
Medic |
(16) |
(18) |
|
|
|
|
|
|
|
|
|
|
|
xi. |
|
Senior SubSea Supervisor |
(9) |
(12) |
(16) |
|
|
|
|
|
|
|
|
|
|
xii. |
|
Senior Materials coordinator |
(10) |
(16) |
|
|
|
|
|
|
|
|
|
|
|
xiii. |
|
Senior Dynamic Position Operator |
(11) |
|
|
|
|
1) |
10-years of experience in all phases of onsite drilling operations. Minimum 2-years of experience as Senior Toolpusher on floating DP rigs. |
2) |
10-years of experience in all phases of onsite drilling operations. Minimum 2 years experience as a Senior Toolpusher on floating DP rigs. |
3) |
7years experience in all phases of onsite drilling operations. Minimum 1 year experience as a Toolpusher on floating DP rigs. |
4) |
5 years experience in all phases of onsite drilling operations. Minimum 2 years experience as a Driller on floating rigs. |
5) |
3 years experience in drilling operations. Minimum 1 year as an Assistant Driller on floating rigs. |
6) |
5 years experience in maintaining and operating related equipment on a drilling unit. |
7) |
5 years experience on an offshore drilling rig. |
8) |
5 years experience as Crane Operator, minimum 3 years onboard offshore drilling units. Minimum 1 year operating experience as a Crane Operator on floaters. Crane Operators must also have current certification. |
9) |
5 years operating experience in offshore drilling operations. Must have thorough knowledge of marine and international regulatory body requirements as they apply to offshore drilling operations. Minimum 1 year as Master on same type of Drilling Unit in drilling mode. |
10) |
5 years experience in operating and maintaining subsea blowout prevention control equipment. |
11) |
3 years experience in warehousing, inventory, and maintenance of adequate stock levels. Must have knowledge of offshore drilling equipment and computerized inventory control systems. |
12) |
5 years experience as Dynamic Position Operator in offshore drilling and marine operations on DP floaters. |
13) |
Current valid IWCF, American BSEE-OCS, Norwegian NPD, or IADC well control certification. Valid shall mean that all well control certificates have not lapsed in accordance with certifying authority. This certificate must be valid for the position in which the individual is employed, i.e., toolpusher with a drillers certificate is not acceptable |
14) |
H2S control and operation certification, as required. |
15) |
Safety, first aid, and fire-fighting certification if applicable as per ships station bill. |
16) |
Master MODU or Unlimited Masters license. |
17) |
Proficient English language skills. |
18) |
DP Advanced Operators Ticket. |
19) |
Trained and certified to international standards as a Medic. Proficient in English language skills. |
Copies of all certificates shall be made available to Company 30 days prior to commencement date of the contract.
c. Shore-Base Personnel
Shore-Base personnel minimum requirements.
i. |
|
Rig Manager |
(1) |
(2) |
(3) |
|
|
1) |
8 years experience in all phases of onsite drilling operations, including 5 years offshore experience and 3 years onshore as Senior Toolpusher/Rig Superintendent/Assistant Rig Manager or Rig Manager. |
2) |
Current Well Control certification. |
3) |
Proficient English language skills. |
d. General
i. |
|
All senior staff positions shall work 35 days on and 35 days off. |
|
|
|
ii. |
|
Contractor may not change Key Personnel without prior approval from Company, such approval shall not be unreasonably withheld. |
|
|
|
iii. |
|
All drill crew personnel shall be fluent in English and are required to have an up to date well control certificate. This certificate must be valid for the position in which the individual is employed, i.e., toolpusher with a drillers certificate is not acceptable. The certificate should be recognized by an appropriate governmental regulatory agency such as the US BSEE or IWCF. |
End of Attachment A3
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ATTACHMENT A4 TO EXHIBIT A SCOPE OF WORK
Offshore Drilling Contract No. PBA 3
APPENDIX A4-I
FINAL ACCEPTANCE FORM
Pursuant to the OFFSHORE DRILLING CONTRACT (Contract) No. PBA 3 dated as of 28 November 2016 (the Effective Date) is made by and between , a corporation, with offices at (Company) and Pacific Bora Limited, a Liberian Company, with representative offices at [ ] and Pacific Drilling Operations Limited, a British Virgin Islands company with representative offices at 11700 Katy Freeway, Houston , Texas 77079 (Collectively Contractor).
Company accepts the Drilling Unit on (Date) at (Time) as fit for purpose as presented in the contract.
Company and Contractor representatives whose signatures are evidenced below hereby agree that the requirements for Final Acceptance as listed in this Attachment A4 to Exhibit A Scope of Work have been met.
The Parties have executed this form as required by OFFSHORE DRILLING CONTRACT (Contract) No. PBA 3 in duplicate as evidenced by the following signatures of authorized representatives of the Parties:
Company: |
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Contractor: | ||||
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|
| ||||
|
|
| ||||
Signature: |
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|
Signature: |
| ||
|
|
| ||||
Name: |
|
|
Name: |
| ||
End of Appendix A4-I
End of Attachment A4
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Pacific Bora Drilling Contract No. PBA 3
ATTACHMENT A5 TO EXHIBIT A SCOPE OF WORK
Offshore Drilling Contract No. PBA 3
CONTRACTOR SAFETY MANAGEMENT SYSTEM
*TO BE ADDED
End of Attachment A5
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Pacific Bora Drilling Contract No. PBA 3
EXHIBIT B DRUG AND ALCOHOL POLICY
Offshore Drilling Contract No. PBA 3
DRUG AND ALCOHOL POLICY
Pacific Bora Drilling Contract No. PBA 3
Copyright © 2009 Pacific Drilling Unpublished Work; all rights reserved.
Document Title: Drug And Alcohol Policy
Document Id.: HSE-WWD_VVP-002
Policy Statement
Pacific Drilling is committed to maintaining a healthy, safe, secure and productive workplace. Alcohol, drug or any other substance abuse causes impairment of judgment and consequently leads to an unacceptable increase in risk of adverse effects to the individual(s) involved, their colleagues and the company as a whole. Therefore, Pacific Drilling is committed to a work place that is free of substance abuse of any kind.
In order to achieve this, and in compliance with any applicable laws and regulations, we will;
· Prohibit the misuse of legitimate drugs and take necessary actions to ensure the legitimate use of prescription drugs is appropriate to the working conditions.
· Prohibit the use, possession, sale, purchase or distribution of illicit or un-prescribed controlled drugs whilst working on or at a Pacific Drilling work site or while working on behalf of Pacific Drilling at any location.
· Prohibit the use, sale, purchase or distribution of alcohol on or in company property unless previously authorized by an appropriate member of senior management.
· Develop and administer a Drug and Alcohol Testing program throughout the company including pre-employment, random, post accident and for cause as appropriate.
· Implement unannounced searches for illicit drugs and/or alcohol on company owned or controlled property.
· Maintain the awareness of all employees and personnel working on behalf of Pacific Drilling with regard to the potential risks associated with drug and alcohol abuse - including the communication of this policy to all personnel.
· Ensure that personnel involved in the administration of any drug and alcohol programs are competent.
· Enforce disciplinary actions, up to and including termination, in the case of violation.
· Regard alcohol or drug dependency as a treatable condition and implement programs to offer assistance to seek treatment to any individual who voluntarily asks for it, provided that the request is received prior to an observed deterioration in job performance or a violation of the Drug and Alcohol policy or any of its supporting programs.
· Monitor the effectiveness of this policy through periodic management review and ensure continual improvement.
These governing principles are in addition to the fundamental obligation of all personnel working for or on behalf of Pacific Drilling to comply with relevant laws, regulations and rules.
This policy shall be regularly reviewed to ensure it is relevant and suitable.
Name: Christian J. Beckett |
|
Job Title: Chief Executive Officer |
|
Signature: |
/s/ Christian J. Beckett |
Exhibit C
Insurance Requirements
Operator
1) Operator shall at Operators expense acquire and maintain, with an insurance company or companies or P&I Clubs authorized to do business in the jurisdiction where the Work is to be performed, rated B+ or better by A. M. Best or equivalent or broker vetted or through a self-insurance program, insurance coverages, of the kind and in the minimum amounts as follows:
a) Adequate Workers Compensation Insurance and Employers Liability Insurance or equivalent insurance complying with applicable local laws with limits of US$1,000,000 covering all Operators employees working under this Agreement. Such policy shall include territorial extensions for all Work and transportation areas as applicable.
b) Commercial (or Public) General Liability Insurance, including contractual liability coverage. The limit shall be US$1,000,000 per occurrence/ US$2,000,000 general aggregate.
c) When Operator services require use of motor vehicles, Operator shall procure Automobile Liability Insurance through an admitted carrier in country and/or state of operations covering all owned, non-owned, hired and/or rented automotive equipment with limits of US$1,000,000 combined single limit each occurrence.
d) When Operator is to furnish transportation by air, Operator shall procure or cause owners of such aircraft to procure Aircraft Liability Insurance with limits of US$10,000,000 combined single limits for Bodily Injury and Property Damage and coverage for the following liabilities: public, passengers, property damage, and airport. Coverage shall be on all owned, rented, and non-owned helicopters and other aircraft and shall include full form Hull insurance with limits equal to the full value of applicable helicopter or other aircraft.
e) When Operator is to furnish transportation by water or other marine services, shall procure full form Hull and Machinery Insurance on American Institute Hull clauses (all risks as amended) or equivalent, including Collision Liability, with the sistership clause unamended. The limits of such insurance shall be the declared value of each vessel (or such other amount as shall be agreed between Operator and Contractor). All such policies shall delete the as owner provision and any other than as owner limitations and delete any provision that allows underwriters to limit liability to anyone other than the vessel owner
f) Operator shall also procure for such vessels full form Protection and Indemnity Insurance on SP-23 clauses or equivalent and insurance for removal of wreck and/or debris, and liability for seepage, pollution, containment, and cleanup, with limits of not less than US$5,000,000 per occurrence (or such other amount as shall be agreed between Operator and Company subject to the Operators insurance policy(ies) terms and conditions).
g) Physical Damage Insurance on Operators property to the extent of its fair market value.
h) Operator shall also procure Operators Extra Expense Insurance in the amount of not less than US$100,000,000 combined single limit per occurrence to cover any and all sums which Operator and/or Contractor may be obligated to incur as expenses and/or liabilities which may be incurred on account of bringing under control an oil or gas well which is out of control or extinguishing an oil or gas well fire, redrilling or repair of loss or damage to an oil or gas well, seepage and pollution, cleanup and contamination arising from operations under this Contract.
i) Excess Liability Insurance over that required in Paragraph 1) (a), (b) and (c) minimum limits of US$10,000,000.
2) Where applicable Operator shall obtain from its insurers a waiver of subrogation (against the Contractor Group in all of the insurance policies listed above (subject to the protective co-insurance clause as applicable). Additionally, the Contractor Group shall be named as additional insureds (or protective co-insureds as applicable) in all such insurance policies (with the exception of Workers Compensation coverage).
3) Operator will furnish to Contractor at email provided or other approved address provided by Contractor a certificate or certificates evidencing the insurance coverages (or their equivalent) listed above. On an ongoing basis, Operator will provide insurance certificates on a no less than annual basis evidencing insurance renewals and material changes to insurance coverages or requirements or for the duration of the contract.
4) The Contractor Group, when allowed by the Operators policy, shall not be liable for premiums unless required by local statute or law. All deductibles or self-insured retentions under such policies shall be for the sole account of Operator. Operator agrees when requested by Contractor to furnish certified copies of all said insurance policies. Failure of Contractor to object to any discrepancies or variations between the certificates of insurance or policies required hereunder and the requirements of this Article shall not be deemed a waiver thereof.
5) In the event that liability for any loss or damage is denied by the Operators insurers, in all or in part, because of breach by Operator of its contract of insurance or for any other reason, or if Operators insurers fail to defend or pay Operators claims, or if Operator fails to maintain any of the insurance herein required, Operator shall hold harmless, defend and indemnify all Contractor Group against any and all damages, liabilities, losses, costs, expenses (including attorneys fees and expenses), claims, demands, and causes of actions of every kind and character (collectively referred to in this Agreement for all purposes as indemnifiable claims) which would otherwise be covered by said insurance. The limits of insurance specified herein are minimum limits only, and notwithstanding anything else to the contrary herein Operators indemnification obligations under this Agreement (express or implied) shall not be limited in amount or in scope to the insurance coverage provided by Operator. The insurance and release, indemnity, and hold harmless provisions of this Agreement are separate and independent covenants, and it shall not be necessary for either Party to exhaust the insurances available to such Party before calling upon the other Party to honor such Partys release, indemnity, and hold harmless obligations under this Agreement.
Contractor
1) Contractor shall at Contractors expense acquire and maintain, with an insurance company or companies or P&I Clubs authorized to do business in the jurisdiction where the Work is to be performed, rated B+ or better by A. M. Best or equivalent or broker vetted or through a self-insurance program, insurance coverages, of the kind and in the minimum amounts as follows:
a) Adequate Workers Compensation Insurance and Employers Liability Insurance or equivalent insurance complying with applicable local laws with limits of US$1,000,000 covering all Contractors onshore employees working under this Agreement. Such policy shall include territorial extensions for all Work and transportation areas as applicable.
b) Commercial (or Public) General Liability Insurance, including contractual liability coverage. The limit shall be US$1,000,000 per occurrence/ US$2,000,000 general aggregate.
c) When contractor services require use of motor vehicles, Contractor shall procure Automobile Liability Insurance through an admitted carrier in country and/or state of operations covering all owned, non-owned, hired and/or rented automotive equipment with limits of US$1,000,000 combined single limit each occurrence.
d) When Contractor is to furnish transportation by air, Contractor shall procure or cause owners of such aircraft to procure Aircraft Liability Insurance with limits of US$10,000,000 combined single limits for Bodily Injury and Property Damage and coverage for the following liabilities: public, passengers, property damage, and airport. Coverage shall be on all owned, rented, and non-owned helicopters and other aircraft and shall include full form Hull insurance with limits equal to the full value of applicable helicopter or other aircraft.
e) Contractor shall procure full form Hull and Machinery Insurance on American Institute Hull clauses (all risks as amended) or equivalent, including Collision Liability, with the sistership clause unamended. The limits of such insurance shall be the declared value of each vessel (or such other amount as shall be agreed between Contractor and Operator). All such policies shall delete the as owner provision and any other than as owner limitations and delete any provision that allows underwriters to limit liability to anyone other than the vessel owner
f) Contractor shall also procure for such vessels full form Protection and Indemnity Insurance on SP-23 clauses or equivalent and insurance for removal of wreck and/or debris, and liability for seepage, pollution, containment, and cleanup, with limits of not less than US$5,000,000 per occurrence (or such other amount as shall be agreed between Contractor and Operator subject to the Contractors insurance policy(ies) terms and conditions).
g) Physical Damage Insurance on Contractors property to the extent of its fair market value.
h) Excess Liability Insurance over that required in Paragraph 1) (a), (b) and (c) minimum limits of US$10,000,000.
2) Where applicable Contractor shall obtain from its insurers a waiver of subrogation (against the Operator Group in all of the insurance policies listed above (subject to the protective co-insurance clause as applicable). Additionally, the Operator Group shall be named as additional insureds (or protective co-insureds as applicable) in all such insurance policies (with the exception of Workers Compensation coverage).
3) Contractor will furnish to Operator at email provided or other approved address provided by Operator a certificate or certificates evidencing the insurance coverages (or their equivalent) listed above. On an ongoing basis, Contractor will provide insurance certificates on a no less than annual basis evidencing insurance renewals and material changes to insurance coverages or requirements or for the duration of the contract.
4) The Operator Group, when allowed by the Contractors policy, shall not be liable for premiums unless required by local statute or law. All deductibles or self-insured retentions under such policies shall be for the sole account of Contractor. Contractor agrees when requested by Operator to furnish certified copies of all said insurance policies. Failure of Operator to object to any discrepancies or variations between the certificates of insurance or policies required hereunder and the requirements of this Article shall not be deemed a waiver thereof.
5) In the event that liability for any loss or damage is denied by the Contractors insurers, in all or in part, because of breach by Contractor of its contract of insurance or for any other reason, or if Contractors insurers fail to defend or pay Contractors claims, or if Contractor fails to maintain any of the insurance herein required, Contractor shall hold harmless, defend and indemnify all Operator Group against any and all damages, liabilities, losses, costs, expenses (including attorneys fees and expenses), claims, demands, and causes of actions of every kind and character (collectively referred to in this Agreement for all purposes as indemnifiable claims) which would otherwise be covered by said insurance. The limits of insurance specified herein are minimum limits only, and notwithstanding anything else to the contrary herein Contractors indemnification obligations under this Agreement (express or implied) shall not be limited in amount or in scope to the insurance coverage provided by Contractor. The insurance and release, indemnity, and hold harmless provisions of this Agreement are separate and independent covenants, and it shall not be necessary for either Party to exhaust the insurances available to such Party before calling upon the other Party to honor such Partys release, indemnity, and hold harmless obligations under this Agreement.
EXHIBIT D - COMPENSATION
Contractor shall be compensated by Company for the Services in accordance with the rates set forth in this Exhibit D Compensation for Services rendered and the Drilling Unit, personnel and all other items furnished by Contractor in conformance with this Contract. Daily rates shall be prorated on the basis of a twenty-four hour calendar day to the nearest one-half hour. No other payments shall be due by Company to Contractor other than those specifically provided for in this Contract. Section numbers and summarized descriptions are provided below for convenience; however, if a conflict exists between this Exhibit and the Contract, the body of the Contract prevails.
I. MOBILIZATION AND DEMOBILIZATION FEES.
1. Mobilization Fee, as per Section 9.1(A): Payable: o Not Payable: x
If payable, amount of Mobilization Fee: ZERO
2. Demobilization Fee, as per Section 9.1(H): Payable: o Not Payable: x
II. DRILLING SERVICES RATES.
All rates are inclusive of any and all other cost (including currency exchange, fees, royalties, operating permit, NCDMB, etc) required to operate in Republic of Guinea, except for taxes (income tax, withholding tax, personal income tax on company personnel, import VAT on CONTRACTOR equipment).
1. Operating Rate, as per Section 9.1(B):
The Operating Rate for one (1) firm well + three (3) 1-well options shall be US$225,000 per day.
2. Moving Rate, as per Section 9.1(C): Payable: x Not Payable: o
If payable, amount of Moving Rate: 90% of Operating Rate
3. International Moving Rate, as per Section 9.1(D): Payable: x Not Payable: o
If payable, amount of International Moving Rate: 98% of Operating Rate
4. Standby Rate, as per Section 9.1(E): 98% of Operating Rate
5. Force Majeure Rate, as per Section 9.1(F): 90% of Operating Rate
6. Redrill Rate, per Section 9.1(G): 50% of Operating Rate
7. Off Weather Rate, as per Section 9.1(I): 100% of Operating Rate
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8. Variation of Service Rates due to a Change in Operating Cost Elements as per 9.3(D):
TOTAL BASELINE OPERATING COSTS:
Drilling Unit Pacific Bora
NOT APPLICABLE FOR THIS CONTRACT
|
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Baseline Cost |
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Base Maintenance Element: |
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|
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Base Labor Cost: |
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Labor & Burden (Offshore) |
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Labor & Burden (Onshore) |
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|
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Total Base Labor Cost |
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Base Catering Cost: |
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|
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xx Contractor Personnel |
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xx Company Personnel |
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Total Base Catering Costs |
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Base Insurance Cost: |
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Total Baseline Operating Costs |
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For purposes of the escalation of Maintenance and Labor Cost, the baselines will be adjusted by using the identified Bureau of Labor Statistics (BLS) Indices in Sections 9.3(D)(4)(b) and 9.3(D)(4)(c), current as of the date of the adjustment request.
III. REIMBURSEMENTS TO CONTRACTOR.
1. Meals and Lodging for Additional Persons, as per Section 10.4:
The Service rates set forth in Part II above include meals and lodging for the following number of Company Persons and those of Companys other contractors: 10
Meals and lodging for additional persons shall be at the following rates:
Meals and/or Lodging: $175 per person per day
2. Reimbursements for Additional Materials & Services, see Sections 7.2(H) and 10.2
IV. MISCELLANEOUS FINANCIAL PROVISIONS.
COMPANYs address for submission of CONTRACTORs paper invoices, as per Section 11.1(A): |
|
CONTRACTORs banking information, as per Section 11.2(D)(1): To Be Provided By Contractor. |
|
|
|
Attn: Mr. Forrest Estep |
|
Name of Bank: xxx |
12012 Wickchester Lane Suite 475 Houston, Texas 77079 |
|
Bank Routing No.: xxx Swift: xxx Account No.: xxx
Name on Account: xxx |
Currency of Payment, as per Section 11.2(D)(3):
Partial payment in Local Currency: Applicable: o Not Applicable: x
Percentage of Compensation payable in:
US Dollar: One Hundred Percent (100%)
Payroll Burden, as per Section 1.1: Payroll Burden shall mean the following percentage of the straight time salary of each of Contractors employees: N/A
Invoice Content and Format, as per Section 11.1: Contractors invoices must contain the following information:
· The title and number of this Contract.
· The amount due in the Currency.
· If applicable, all the following:
· The amount of local currency due.
· The value added tax, goods and services tax, sales tax or other taxes which Contractor proposes to collect or for which it will seek reimbursement from Company (including a tax assessed against Company but collected by Contractor).
· Contractors tax registration number.
Accelerated Payment Program
The Accelerated Payment Program is not applicable to this Contract.
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END OF EXHIBIT D