Transocean : Fleet Status Report, dated October 25, 2021 - Form 8-K

Updated: October 25, 2021

Revisions Noted in Bold

Dynamically positioned "DP" «

Dayrate on

Dayrate on

Yr. (1)

Water

Drilling

Estimated

Estimated

Current

Previous

Footnote

Floater

Entered

Depth

Depth

Contract

Expiration

Contract (3)

Contract (3)

Rig Type/Name

References

Type

DP

Service

(Feet)

(Feet)

Location

Customer

Start Date (2)

Date (2)

(Dollars)

(Dollars)

Additional Comments

Rigs Under Construction (2)

Deepwater Atlas

(8), (15)

ship

*

TBA

12,000

40,000

USGOM

BOE

Q3 2022

Q2 2023

315,000

N/A

Q3 2023

Q2 2023

185,000

N/A

20,000 psi BOP installation

(8)

Q2 2023

Q1 2024

455,000

N/A

Deepwater Titan

(6), (15)

ship

*

TBA

12,000

40,000

USGOM

Chevron

Q1 2023

Q1 2028

455,000

N/A

Ultra-Deepwater (27)

Deepwater Poseidon

(6)

ship

*

2018

12,000

40,000

USGOM

Shell

Sep-18

Feb-28

473,000

N/A

Deepwater Pontus

(6)

ship

*

2017

12,000

40,000

USGOM

Shell

Oct-17

Oct-27

473,000

N/A

Deepwater Conqueror

(6), (8)

ship

*

2016

12,000

40,000

USGOM

Chevron

Dec-16

Dec-21

579,000

N/A

(6), (8)

USGOM

Chevron

Jan-22

Oct-22

335,000

N/A

Deepwater Proteus

(6)

ship

*

2016

12,000

40,000

USGOM

Shell

Aug-16

May-26

474,000

N/A

Deepwater Thalassa

(6)

ship

*

2016

12,000

40,000

USGOM

Shell

Jul-16

Feb-26

475,000

N/A

Ocean Rig Apollo

ship

*

2015

12,000

40,000

Stacked May-16

Deepwater Asgard

ship

*

2014

12,000

40,000

USGOM

Beacon

Jul-21

Sep-21

240,000

N/A

USGOM

Beacon

Sep-21

Oct-21

280,000

N/A

Includes MPD Services

USGOM

Not Disclosed

Jan-22

Apr-22

295,000

N/A

Includes MPD Services

Deepwater Invictus

(6)

ship

*

2014

12,000

40,000

USGOM

BHP Billiton

Jun-21

Sep-21

215,000

N/A

USGOM

BHP Billiton

Oct-21

Mar-22

260,000

215,000

USGOM

BHP Billiton

Mar-22

May-22

295,000

260,000

Ocean Rig Athena

ship

*

2014

12,000

40,000

Stacked Mar-17

Deepwater Skyros

ship

*

2013

12,000

40,000

Angola

Total

Dec-18

Dec-21

573,000

N/A

(8), (13)

Angola

Total

Dec-21

Dec-22

195,000

N/A

Ocean Rig Mylos

ship

*

2013

12,000

40,000

Stacked Sep-16

Deepwater Corcovado

(7), (8)

ship

*

2011

10,000

35,000

Brazil

Petrobras

Dec-19

Jul-23

189,000

N/A

Deepwater Mykonos

(7), (8)

ship

*

2011

10,000

35,000

Brazil

Petrobras

Nov-19

Aug-23

208,000

N/A

Ocean Rig Olympia

ship

*

2011

10,000

35,000

Stacked Apr-16

Deepwater Orion

ship

*

2011

10,000

35,000

Idle Oct-19

Deepwater Champion

ship

*

2011

12,000

40,000

Stacked Feb-16

Discoverer Inspiration

ship

*

2010

12,000

40,000

USGOM

Hess

Oct-21

May-22

215,000

N/A

Discoverer India

ship

*

2010

12,000

40,000

Stacked Jul-20

Dhirubhai Deepwater KG2

ship

*

2010

12,000

35,000

Brunei

Brunei Shell Petroleum

Dec-21

Dec-21

190,000

N/A

Discoverer Luanda

ship

*

2010

7,500

40,000

Stacked Feb-18

Discoverer Americas

ship

*

2009

12,000

40,000

Stacked Apr-16

Discoverer Clear Leader

ship

*

2009

12,000

40,000

Stacked Jun-19

Petrobras 10000

(6), (7), (16)

ship

*

2009

12,000

37,500

Brazil

Petrobras

Oct-21

Mar-22

316,000

N/A

(6), (7), (16)

Brazil

Petrobras

Mar-22

Mar-23

323,000

N/A

(6), (7), (16)

Brazil

Petrobras

Mar-23

Oct-23

329,000

N/A

Dhirubhai Deepwater KG1

(14), (17)

ship

*

2009

12,000

35,000

India

Reliance

Sep-21

Dec-21

158,000

144,000

29 days out of service in Q4 2021

(14)

Dec-21

Nov-22

158,000

Development Driller III

semi

*

2009

7,500

37,500

Trinidad

BHP Billiton

Jun-21

Oct-21

220,000

N/A

Trinidad

BHP Billiton

Nov-21

Nov-21

220,000

N/A

GSF Development Driller I

semi

*

2005

7,500

37,500

Stacked Nov-20

Deepwater Nautilus

semi

2000

8,000

30,000

Not Disclosed

POSCO

Jul-21

Aug-21

135,000

N/A

Not Disclosed

POSCO

Aug-21

Sep-21

135,000

N/A

Not Disclosed

POSCO

Sep-21

Nov-21

135,000

N/A

Not Disclosed

POSCO

Nov-21

Dec-21

135,000

N/A

(9)

Not Disclosed

Not Disclosed

Feb-22

Apr-22

145,000

N/A

Q4 2021	Q1 2022	Q2 2022	Q3 2022
Estimated Average Contract Dayrates (5)	$327,000	$307,000	$321,000	$327,000

Harsh Environment (10)

Transocean Norge

(12)

semi

*

2019

10,000

40,000

Norway

ConocoPhillips

Mar-22

Sep-22

280,000

N/A

Transocean Enabler

(6), (7), (8)

semi

*

2016

1,640

28,000

Norway

Equinor

Jul-21

Jul-22

441,000

N/A

(6), (7), (8)

Norway

Equinor

Jul-22

Jul-23

436,000

N/A

(6), (7), (8)

Norway

Equinor

Jul-23

Mar-24

426,000

N/A

Transocean Encourage

(6), (7), (8)

semi

*

2016

1,640

28,000

Norway

Equinor

Mar-21

Mar-22

437,000

N/A

(6), (7), (8)

Norway

Equinor

Mar-22

Mar-23

432,000

N/A

(6), (7), (8)

Norway

Equinor

Mar-23

Nov-23

423,000

N/A

Transocean Endurance

(6), (8)

semi

*

2015

1,640

28,000

Norway

Equinor

Dec-20

Dec-21

492,000

N/A

(6), (8)

Norway

Equinor

Dec-21

Dec-22

488,000

N/A

(6), (8)

Norway

Equinor

Dec-22

Jun-23

477,000

N/A

Transocean Equinox

(6), (8)

semi

*

2015

1,640

28,000

Norway

Equinor

Nov-20

Nov-21

492,000

N/A

(6), (8)

Norway

Equinor

Nov-21

Nov-22

488,000

N/A

(6), (8)

Norway

Equinor

Nov-22

Dec-22

477,000

N/A

Transocean Spitsbergen

(7), (8)

semi

*

2010

10,000

30,000

Norway

Equinor

Oct-19

Jun-22

Not Disclosed

N/A

(7), (8)

Norway

Equinor

Jun-22

Aug-22

287,000

N/A

(7), (8)

Norway

Equinor

Aug-22

Sep-22

287,000

N/A

Transocean Barents

(4), (7), (8)

semi

*

2009

10,000

30,000

Norway

Shell

Feb-22

Aug-22

296,000

N/A

Paul B. Loyd, Jr.

(7)

semi

1990

2,000

25,000

UKNS

Harbour Energy

Aug-21

Oct-21

Not Disclosed

N/A

Transocean Leader

semi

1987/1997

4,500

25,000

Stacked Jul-20

Henry Goodrich

semi

1985/2007

5,000

30,000

Stacked Mar-20

Q4 2021	Q1 2022	Q2 2022	Q3 2022
Estimated Average Contract Dayrates (5)	$401,000	$405,000	$387,000	$396,000

Fixed-Price Options - See Footnote 10

Ultra-Deepwater

Dhirubhai Deepwater KG2

ship

*

2010

12,000

35,000

Brunei

Brunei Shell Petroleum

Dec-21

Jan-22

190,000

N/A

Brunei

Brunei Shell Petroleum

Jan-22

Mar-22

190,000

N/A

Transocean Norge

(12)

semi

*

2019

10,000

40,000

Norway

ConocoPhillips

Sep-22

Nov-22

280,000

N/A

(12)

Norway

ConocoPhillips

Nov-22

Dec-22

280,000

N/A

Harsh Environment

Transocean Enabler

(6), (7), (8), (11)

semi

*

2016

1,640

28,000

Norway

Equinor

Mar-24

Mar-27

426,000

N/A

(6), (7), (8), (11)

Norway

Equinor

Mar-27

Mar-30

426,000

N/A

(7), (8)

Norway

Equinor

Mar-30

Mar-33

426,000

N/A

(7), (8)

Norway

Equinor

Mar-33

Mar-36

426,000

N/A

Transocean Encourage

(6), (7), (8), (11)

semi

*

2016

1,640

28,000

Norway

Equinor

Nov-23

Nov-26

423,000

N/A

(6), (7), (8), (11)

Norway

Equinor

Nov-26

Nov-29

423,000

N/A

(7), (8)

Norway

Equinor

Nov-29

Nov-32

423,000

N/A

(7), (8)

Norway

Equinor

Nov-32

Nov-35

423,000

N/A

Transocean Endurance

(6), (8), (11)

semi

*

2015

1,640

28,000

Norway

Equinor

Jun-23

Jun-26

492,000

N/A

(6), (8), (11)

Norway

Equinor

Jun-26

Jun-29

492,000

N/A

(6), (8)

Norway

Equinor

Jun-29

Jun-32

492,000

N/A

(6), (8)

Norway

Equinor

Jun-32

Jun-35

492,000

N/A

Transocean Equinox

(6), (8), (11)

semi

*

2015

1,640

28,000

Norway

Equinor

Dec-22

Dec-25

492,000

N/A

(6), (8), (11)

Norway

Equinor

Dec-25

Dec-28

492,000

N/A

(6), (8)

Norway

Equinor

Dec-28

Dec-31

492,000

N/A

(6), (8)

Norway

Equinor

Dec-31

Dec-34

492,000

N/A

Revisions Noted in Bold ​
Footnotes
(1)​	Dates shown are the original service date and the date of the most recent upgrade, if any.
(2)​	Estimated Contract Start and Estimated Expiration Dates are generally calculated as follows: (1) for events estimated to occur between the 1st and 15th of a month, the previous month is reported (i.e. a contract which is estimated to commence on March 4, 2021 will be reported as commencing in February 2018) and (2) for events estimated to occur between the 16th and the end of a month, the actual month is reported (i.e. a contract which is estimated to commence on March 24, 2021 will be reported as commencing in March 2021). Expiration dates represent the company's current estimate of the earliest date the contract for each rig is likely to expire. Some rigs have two or more contracts in continuation, so the last line shows the estimated earliest availability. Many contracts permit the customer to extend the contract.
(3)​	Represents the full operating dayrate, although the average dayrate over the term of the contract will be lower and could be substantially lower. Does not reflect incentive programs which are typically based on the rig's operating performance against a performance curve. Please refer to the "Customer Contract Duration, Timing and Dayrates and Risks Associated with Operations" section of the Disclaimers & Definitions for a description of dayrates. This column may not reflect the rate currently being received under the contract as a result of an applicable standby rate or other rate, which typically is less than the contract dayrate.
(4)​	Contractual dayrate of $302,000 has been updated to reflect current effect of foreign currency component.
(5)​	Estimated Average Contract Dayrate is defined as the average contracted full operating dayrate to be earned per revenue earning day. See note (3) for definition of full operating dayrate.
(6)​	If the dayrate is disclosed, reflects the current contracted dayrate which could reflect prior cost escalations, or de-escalations, and could change in the future due to further cost escalations, or de-escalations.
(7)​	If the dayrate is disclosed, reflects the current contracted dayrate which, along with costs, includes a foreign currency component. Changes in the value of the U.S. Dollar relative to certain foreign currencies will result in an adjustment to the dayrate according to the terms of the contract. The dayrate adjustment generally offsets the foreign currency exchange-related change in costs.
(8)​	If the dayrate is disclosed, the contract provides for a bonus incentive opportunity not reflected in the current contract dayrate.
(9)​	Mobilization to the new contract location is in direct continuation of prior contract.
(10)​	Fixed price options may be exercised at the customer's discretion. During periods when dayrates on new contracts are increasing relative to existing contracts, the likelihood of customers' exercising fixed price options increases. During periods when dayrates on new contracts are decreasing relative to existing contracts, the likelihood of customers' exercising fixed price options declines.
(11)​	If exercised, a lump sum payment of $12.5 million shall be payable to the customer upon commencement of the option period.
(12)​	We hold a 33.0% ownership interest in the unconsolidated company owning the rig. Our customer has entered into the drilling contract with the operating company, a wholly owned subsidiary. Our contract backlog includes and we will recognize 100% of the contract drilling revenues associated with the drilling contract.

(13)​	The disclosed dayrate was mutually agreed upon between Transocean and Total in 2020 with respect to a pre-existing unpriced option that was originally granted by Ocean Rig and the applicable dayrate does not necessarily reflect market rates prevailing at the time of this report.
(14)​	The contract includes a quarterly dayrate escalation mechanism that may increase or decrease the dayrate with a floor of $127,000.
(15)​	The contract is expected to start in the period indicated. Factors that could influence the contract start date include shipyard delivery, customer acceptance, and mobilization to operating location, among others.
(16)​	The dayrate disclosed excludes a 5% royalty related to Transocean's dual activity patent.
(17)​	The quarterly dayrate escalation mechanism increased dayrate to $144,000 from June 23, 2021 to September 22, 2021.

Disclaimers & Definitions
The information contained in this Fleet Status Report (the "Information") is as of the date of the report only and is subject to change without notice to the recipient. Transocean Ltd. assumes no duty to update any portion of the Information.
DISCLAIMER. NEITHER TRANSOCEAN LTD. NOR ITS AFFILIATES MAKE ANY EXPRESS OR IMPLIED WARRANTIES (INCLUDING, WITHOUT LIMITATION, ANY WARRANTY OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE OR USE) REGARDING THE INFORMATION CONTAINED IN THIS REPORT, WHICH INFORMATION IS PROVIDED "AS IS." Neither Transocean Ltd. nor its affiliates will be liable to any recipient or anyone else for any inaccuracy, error or omission, regardless of cause, in the information set forth in this report or for any damages (whether direct or indirect, consequential, punitive or exemplary) resulting therefrom. ​
No Unauthorized Publication or Use. All information provided by Transocean in this report is given for the exclusive use of the recipient and may not be published, redistributed or retransmitted without the prior written consent of Transocean.
Customer Contract Duration, Timing and Dayrates and Risks Associated with Operations. The duration and timing (including both starting and ending dates) of the customer contracts are estimates only, and customer contracts are subject to cancellation, suspension and delays for a variety of reasons, including some beyond the control of Transocean. Also, the dayrates set forth in the report are estimates based upon the full contractual operating dayrate. However, the actual average dayrate earned over the course of any given contract will be lower and could be substantially lower. The actual average dayrate will depend upon a number of factors (rig downtime, suspension of operations, etc.) including some beyond the control of Transocean. Our customer contracts and operations are generally subject to a number of risks and uncertainties, and we urge you to review the description and explanation of such risks and uncertainties in our filings with the Securities and Exchange Commission (SEC), which are available free of charge on the SEC's website at www.sec.gov. The dayrates do not include revenue for mobilizations, demobilizations, upgrades, shipyards or recharges.
Out of Service. The time associated with committed shipyards, upgrades, surveys, repairs, regulatory inspections, contract preparation or other committed activity on the rig and is not expected to earn an operating dayrate, Contract preparation refers to periods during which the rig is undergoing modifications or upgrades as a result of contract requirements. ​
•	The references included in this Fleet Status Report may not be firm and could change significantly based on a variety of factors. Any significant changes to our estimates of out of service time will be reflected in subsequent Fleet Status Reports, as applicable. ​
•	In some instances such as certain mobilizations, upgrades and shipyards, we are paid compensation by our customers that is generally recognized over the life of the primary contract term of the drilling contract.
Forward-Looking Statement. The statements made in the Fleet Update that are not historical facts are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward-looking statements made in the Fleet Update include, but are not limited to, statements involving the estimated duration of customer contracts, contract dayrate amounts, future contract commencement dates and locations and planned shipyard projects and other out of service time. Such statements are subject to numerous risks, uncertainties and assumptions, including but not limited to, uncertainties relating to the level of activity in offshore oil and gas exploration and development, exploration success by producers, oil and gas prices, competition and market conditions in the contract drilling industry, shipyard delays, actions and approvals of third parties, possible cancellation or suspension of drilling contracts as a result of mechanical difficulties or performance, Transocean's ability to enter into and the terms of future contracts, the availability of qualified personnel, labor relations and the outcome of negotiations with unions representing workers, operating hazards, factors affecting the duration of contracts including well-in-progress provisions, the actual amount of downtime, factors resulting in reduced applicable dayrates, hurricanes and other weather conditions,

terrorism, political and other uncertainties inherent in non-U.S. operations (including the risk of war, civil disturbance, seizure or damage of equipment and exchange and currency fluctuations), the impact of governmental laws and regulations, the adequacy of sources of liquidity, the effect of litigation and contingencies and other factors described above and discussed in Transocean's most recently filed Form 10-K, in Transocean's Forms 10-Q for subsequent periods and in Transocean's other filings with the SEC, which are available free of charge on the SEC's website at www.sec.gov. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual results may vary materially from those indicated. You should not place undue reliance on forward-looking statements. Each forward-looking statement speaks only as of the date of the particular statement, and we undertake no obligation to publicly update or revise any forward looking statements, except as required by law.

Fleet Classifications. Transocean uses classifications for its drillships, semisubmersibles, and jackup rigs.The classifications reflect the company's strategic focus on the ownership and operations of premium, high-specification units and are approximately as follows: "Ultra-Deepwater" are the latest generation of drillships and semisubmersible rigs and are capable of drilling in water depths equal to or greater than 7,500 feet; "Deepwater" rigs are drillships and semisubmersible rigs capable of drilling in water depths equal to or greater than 4,500 feet and less than 7,500 feet; "Harsh Environment" are premium rigs equipped for year-round operations in harsh environments; "Midwater Floaters" are semisubmersible rigs capable of drilling in water depths of greater than 300 feet and up to 4,499 feet.

Stacking. An "Idle" rig is primarily between contracts, readily available for operations, and operating costs are typically at or near normal levels. A "Stacked" rig, on the other hand, is primarily manned by a reduced crew or unmanned and typically has reduced operating costs and is (i) preparing for an extended period of inactivity, (ii) expected to continue to be inactive for an extended period, or (iii) completing a period of extended inactivity. However, stacked rigs will continue to incur operating costs at or above normal operating costs for approximately 30 days following initiation of stacking.