Transocean Ltd. - FORM 8-K - EX-99.1

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8-K - CURRENT REPORT OF MATERIAL EVENTS OR CORPORATE CHANGES - Transocean Ltd.	a12-24373_18k.htm

Exhibit 99.1

		Transocean Ltd. (NYSE: RIG), (SIX: RIGN) Fleet Status Report
Updated: October 17, 2012
Revisions Noted in Bold
Dynamically positioned *


				Yr. (1)	Water	Drilling			Estimated	Estimated	Dayrate on Current	Dayrate on Previous	Estimated Out of Service Days (4)						Estimated Out of Service Days (4)
	Footnote	Floater	Dynamically	Entered	Depth	Depth			Contract	Expiration	Contract (3)	Contract (3)	2012						2013
Rig Type/Name	References	Type	Positioned	Service	(Feet)	(Feet)	Location	Customer	Start Date (2)	Date (2)	(Dollars)	(Dollars)	Q2		Q3		Q4		Q1		Q2		Q3		Q4
*Rigs Under Construction (9)*

Deepwater Asgard	(26)	ship	*	TBA	12,000	40,000						N/A	—		—		—		—		—		—		—
Deepwater Invictus	(11)	ship	*	TBA	12,000	40,000	USGOM	TBA	Q2 2014	Q2 2017	595,000	N/A	—		—		—		—		—		—		—
DSME 12000 Drillship TBN1	(6), (11)	ship	*	TBA	12,000	40,000	TBA	Shell	Q4 2015	Q4 2025	519,000	N/A	—		—		—		—		—		—		—
DSME 12000 Drillship TBN2	(6), (11)	ship	*	TBA	12,000	40,000	TBA	Shell	Q2 2016	Q2 2026	519,000	N/A	—		—		—		—		—		—		—
DSME 12000 Drillship TBN3	(6), (11)	ship	*	TBA	12,000	40,000	TBA	Shell	Q4 2016	Q4 2026	519,000	N/A	—		—		—		—		—		—		—
DSME 12000 Drillship TBN4	(6), (11)	ship	*	TBA	12,000	40,000	TBA	Shell	Q1 2017	Q1 2027	519,000	N/A	—		—		—		—		—		—		—
Transocean Siam Driller	(6), (11)			TBA	350	35,000	Thailand	Chevron	Q1 2013	Q1 2018	135,000	N/A	—		—		—		—		—		—		—
Transocean Andaman	(6), (11)			TBA	350	35,000	Thailand	Chevron	Q2 2013	Q2 2016	145,000	N/A	—		—		—		—		—		—		—
Transocean Ao Thai	(6), (11)			TBA	350	35,000	Thailand	Chevron	Q4 2013	Q4 2018	135,000	N/A	—		—		—		—		—		—		—

High Specification Floater: Ultra-Deepwater (27)

Discoverer Americas	(6)	ship	*	2009	12,000	40,000	USGOM	Statoil	Mar-11	Mar-14	509,000	486,000	—		—		—		—		—		—		—
Deepwater Champion	(6)	ship	*	2011	12,000	40,000	USGOM	ExxonMobil	Jun-12	Nov-15	666,000	655,000	—		—		—		—		—		—		10
Discoverer Clear Leader	(6), (14)	ship	*	2009	12,000	40,000	USGOM	Chevron	Sep-10	Aug-14	561,000	503,000	—		—		—		—		—		—		—
Discoverer Inspiration	(6)	ship	*	2010	12,000	40,000	USGOM	Chevron	Sep-10	Mar-15	516,000	494,000	7		—		—		—		—		—		—
Dhirubhai Deepwater KG1		ship	*	2009	12,000	35,000	India	Reliance	Aug-09	Jul-14	510,000	N/A	—		—		—		—		—		—		—
Dhirubhai Deepwater KG2		ship	*	2010	12,000	35,000	India	Reliance	Mar-12	Feb-15	510,000	573,000	—		—		—		—		—		—		—
Discoverer India	(16)	ship	*	2010	12,000	40,000	USGOM	Reliance	Aug-11	Sep-13	499,000	508,000	—		—		—		—		—		—		12
							India	Reliance	Sep-13	Mar-21	508,000	499,000
Petrobras 10000	(6), (7), (8)	ship	*	2009	12,000	37,500	Brazil	Petrobras	Feb-11	Aug-19	421,000	N/A	—		—		—		—		—		—		—
Discoverer Deep Seas	(6)	ship	*	2001	10,000	35,000	USGOM	Chevron	Feb-11	Feb-13	456,000	517,000	—		—		—		12		—		—		—
							USGOM	Murphy Oil	Mar-13	Mar-16	595,000	456,000
Discoverer Enterprise	(6)	ship	*	1999	10,000	35,000	USGOM	BP	Jan-11	Jan-13	435,000	523,000	—		—		—		—		—		—		—
	(6)						USGOM	BP	Jan-13	Jan-14	492,000	435,000
Discoverer Spirit	(6), (19)	ship	*	2000	10,000	35,000	USGOM	Anadarko	Jul-12	May-14	540,000	564,000	—		—		—		—		—		7		—
GSF C.R. Luigs	(6)	ship	*	2000	10,000	35,000	USGOM	BHP Billiton	Dec-11	Feb-14	532,000	411,000	—		—		—		—		10		—		—
GSF Jack Ryan	(6)	ship	*	2000	10,000	35,000	Nigeria	Total	Jun-09	Jul-14	425,000	297,000	45		—		—		—		—		—		—
Deepwater Discovery	(6), (7)	ship	*	2000	10,000	30,000	Brazil	BP	Aug-11	Aug-13	463,000	425,000	—		—		—		—		—		14		—
Deepwater Frontier	(6)	ship	*	1999	10,000	30,000	Australia	ExxonMobil	Mar-12	May-14	475,000	477,000	—		—		—		—		—		—		—
Deepwater Millennium	(6), (25)	ship	*	1999	10,000	30,000	Mozambique	Anadarko	Jan-12	Aug-13	545,000	576,000	—		—		—		—		—		—		—
Deepwater Pathfinder	(6)	ship	*	1998	10,000	30,000	USGOM	Eni	Aug-10	Apr-15	672,000	550,000	—		—		—		—		—		12		—
Deepwater Expedition		ship	*	1999	8,500	30,000	TBA	TBA	Nov-12	Nov-14	650,000	640,000	45		44		61		—		—		—		—
Cajun Express	(6), (7)	semi	*	2001	8,500	35,000	Brazil	Petrobras	May-10	Jul-13	518,000	493,000	—		—		13		—		—		—		—
Deepwater Nautilus	(6), (8)	semi		2000	8,000	30,000	USGOM	Shell	Aug-12	Aug-17	525,000	551,000	—		—		—		—		—		—		—
GSF Explorer	(25)	ship	*	1972/1998	7,800	30,000							—		7		73		10		—		—		—
Discoverer Luanda	(6), (15)	ship	*	2010	7,500	40,000	Angola	BP	Jan-11	Jan-18	470,000	N/A	—		—		15		—		—		—		—
GSF Development Driller I	(6), (25)	semi	*	2005	7,500	37,500	USGOM	BHP Billiton	Jun-08	Oct-12	525,000	220,000	—		—		—		—		47		24		—
							USGOM	BHP Billiton	Oct-12	Aug-14	580,000	525,000
GSF Development Driller II	(6)	semi	*	2005	7,500	37,500	USGOM	BP	Nov-08	Nov-13	580,000	208,000	—		—		—		—		—		—		7
Development Driller III	(6)	semi	*	2009	7,500	37,500	USGOM	BP	Nov-09	Nov-16	403,000	N/A	—		—		—		—		—		—		—
Sedco Energy		semi	*	2001	7,500	35,000	Ghana	Tullow	Oct-11	Oct-13	440,000	N/A	—		—		—		14		—		—		—
Sedco Express	(6), (7)	semi	*	2001	7,500	35,000	Israel	Noble Energy	May-12	Dec-12	500,000	490,000	—		—		—		55		—		—		—
	(7)						Nigeria	ENI	Feb-13	Oct-14	600,000	500,000
										Total Estimated Days Out of Service			97		51		162		91		57		57		29
										Estimated Average Contract Dayrate(5)			$	504,000	$	511,000	$	515,000	$	520,000	$	526,000	$	526,000	$	530,000

High Specification Floater: Deepwater (14)


Deepwater Navigator	(7), (8), (20)	ship	*	1971/2000	7,200	25,000	Brazil	Petrobras	May-11	Feb-16	366,000	190,000	—		—		—		—		—		—		—
Discoverer Seven Seas	(25)	ship	*	1976/1997	7,000	25,000	Indonesia	ENI	Mar-12	Oct-12	445,000	295,000	8		—		46		31		—		—		—
							Sri Lanka	Cairn Energy	Jan-13	Mar-13	490,000	445,000
Transocean Marianas	(6)	semi		1979/1998	7,000	30,000	Ghana	ENI	Feb-11	Dec-12	456,000	450,000	—		—		6		31		—		—		—
	(8)						Namibia	HRT	Jan-13	Oct-13	530,000	456,000
Sedco 706	(6), (7)	semi	*	1976/1994/ 2008	6,500	25,000	Brazil	Chevron	Apr-09	Apr-14	311,000	N/A	—		—		—		—		—		—		—
Sedco 702	(6), (7), (25)	semi	*	1973/2007	6,500	25,000	Nigeria	Shell	Sep-12	Jan-16	461,000	357,000	13		46		—		—		—		61		39
Sedco 707	(7), (8), (20), (25)	semi	*	1976/1997	6,500	25,000	Brazil	Petrobras	Nov-09	Nov-14	384,000	188,000	27		92		92		90		79		—		—
GSF Celtic Sea	(6)	semi		1982/1998	5,750	25,000	Angola	ExxonMobil	Aug-12	Aug-13	324,000	320,000	—		—		—		—		—		—		—
	(6)						Angola	ExxonMobil	Aug-13	Aug-14	328,000	324,000
	(6)						Angola	ExxonMobil	Aug-14	Sep-14	332,000	328,000
Jack Bates		semi		1986/1997	5,400	30,000	Australia	Santos	Jul-12	Jun-13	380,000	380,000	6		5		—		—		—		—		—
Sedco 709		semi	*	1977/1999	5,000	25,000	Malaysia			Stacked			—		—		—		—		—		—		—
M.G. Hulme, Jr.	(7), (25)	semi		1983/1996	5,000	25,000	India	ONGC	Sep-11	Apr-13	213,000	N/A	—		—		—		—		—		—		77
Transocean Richardson		semi		1988	5,000	25,000	Malaysia			Stacked			—		—		—		—		—		—		—
Sedco 710	(7), (8), (20)	semi	*	1983/2001	4,500	25,000	Brazil	Petrobras	Oct-10	Sep-16	278,000	128,000	28		—		—		—		—		—		21
Transocean Rather		semi		1988	4,500	25,000	Angola	ExxonMobil	Oct-12	May-13	350,000	437,000	—		10		23		—		—		—		—
Sovereign Explorer		semi		1984	4,500	25,000	USGOM			Stacked			—		—		—		—		—		—		—
										Total Estimated Days Out of Service			82		153		167		152		79		61		137
										Estimated Average Contract Dayrate(5)			$	354,000	$	355,000	$	351,000	$	358,000	$	368,000	$	371,000	$	362,000

				Yr. (1)	Water	Drilling			Estimated	Estimated	Dayrate on Current	Dayrate on Previous	Estimated Out of Service Days (4)						Estimated Out of Service Days (4)
	Footnote	Floater	Dynamically	Entered	Depth	Depth			Contract	Expiration	Contract (3)	Contract (3)	2012						2013
Rig Type/Name	References	Type	Positioned	Service	(Feet)	(Feet)	Location	Customer	Start Date (2)	Date (2)	(Dollars)	(Dollars)	Q2		Q3		Q4		Q1		Q2		Q3		Q4
High Specification Floater: Harsh Environment (7)
Transocean Barents	(6), (7),(23)	semi	*	2009	10,000	30,000	NNS	DNO	Jul-12	Jan-13	512,000	552,000	—		—		—		—		—		—		—
	(6), (7)						NNS	DNO	Jan-13	Jul-14	569,000	512,000
Transocean Spitsbergen	(6), (7), (22)	semi	*	2010	10,000	30,000	NNS	Statoil	Oct-11	Jul-13	500,000	N/A	—		—		—		—		—		—		—
							NNS	Statoil	Jul-13	Jul-15	542,000	500,000
Henry Goodrich	(6)	semi		1985/2007	5,000	30,000	Canada	Husky	Oct-10	Jan-14	341,000	381,000	23		28		36		—		—		—		—
Transocean Leader	(6), (7), (25)	semi		1987/1997	4,500	25,000	NNS	Statoil	Mar-12	Mar-15	413,000	469,000	—		28		92		3		—		—		—
Paul B. Loyd, Jr.	(6), (7), (13), (25)	semi		1990	2,000	25,000	UKNS	BP	Mar-12	Sep-13	346,000	517,000	—		—		—		—		—		—		61
	(6), (7)						UKNS	BP	Sep-13	Mar-15	442,000	346,000
Transocean Arctic	(6), (7)	semi		1986	1,650	25,000	NNS	Rig Management Norway	Jul-12	Jun-13	427,000	292,000	—		—		—		—		—		—		—
							NNS	Rig Management Norway	Jun-13	Feb-14	419,000	427,000
Polar Pioneer	(6), (7)	semi		1985	1,500	25,000	NNS	Statoil	Feb-10	Jan-14	523,000	309,000	—		—		—		—		—		—		—
										Total Estimated Days Out of Service			23		56		128		3		—		—		61
										Estimated Average Contract Dayrate(5)			$	421,000	$	442,000	$	446,000	$	442,000	$	445,000	$	451,000	$	464,000

Midwater Floaters (25)
Sedco 700		semi		1973/1997	3,600	25,000	Malaysia			Stacked			—		—		—		—		—		—		—
Transocean Legend	(25)	semi		1983	3,500	25,000	Australia	Conoco Phillips	Mar-12	Oct-13	293,000	300,000	—		—		—		—		—		35		—
Transocean Amirante	(25)	semi		1978/1997	3,500	25,000	Egypt	Burullus Gas Company	Jun-12	Dec-12	275,000	247,000	—		—		—		—		7		92		33
							Egypt	Burullus Gas Company	Dec-12	Jun-13	305,000	275,000
GSF Arctic I	(6), (7)	semi		1983/1996	3,400	25,000	Brazil	Vanco	Jun-12	Jan-13	270,000	250,000	90		—		—		45		43		—		—
C. Kirk Rhein, Jr.		semi		1976/1997	3,300	25,000	Malaysia			Stacked			—		—		—		—		—		—		—
Transocean Driller	(7), (8)	semi		1991	3,000	25,000	Brazil	Petrobras	Jul-10	Jul-16	259,000	116,000	—		—		—		21		—		—		—
GSF Rig 135	(17), (25)	semi		1983	2,800	25,000	Nigeria	ENI	May-12	Dec-12	340,000	260,000	—		—		13		73		—		—		—
							Congo	Total	Mar-13	Feb-15	365,000	340,000
GSF Rig 140	(6)	semi		1983	2,800	25,000	India	ONGC	Mar-12	Mar-14	260,000	N/A	9		—		—		—		—		—		—
Falcon 100	(7), (8)	semi		1974/1999	2,400	25,000	Brazil	Petrobras	Mar-08	Mar-13	238,000	180,000	—		—		—		—		—		—		—
GSF Aleutian Key		semi		1976/1999/ 2001	2,300	25,000	Gabon			Stacked			—		—		—		—		—		—		—
Sedco 703		semi		1973/1995	2,000	25,000	Malaysia			Stacked			—		—		—		—		—		—		—
Sedco 711	(25)	semi		1982	1,800	25,000	UKNS	Talisman	Jun-12	Nov-12	265,000	See Footnote 9	2		27		—		—		—		64		66
	(6), (24)						UKNS	Talisman	Nov-12	Jul-13	275,000	265,000			—		—		—		—		—		—
	(6)						UKNS	Talisman	Nov-13	Nov-15	350,000	275,000			—		—		—		—		—		—
Transocean John Shaw	(7), (13), (25)	semi		1982	1,800	25,000	UKNS	Taqa	Mar-12	Nov-12	277,000	246,000	—		—		—		—		—		—		31
							UKNS	EOG	Nov-12	Dec-12	307,000	277,000
	(7)						UKNS	Taqa	Dec-12	Sep-13	323,000	307,000
							UKNS	Taqa	Sep-13	Dec-14	363,000	323,000
GSF Arctic III	(7)	semi		1984	1,800	25,000	UKNS	Nexen	Sep-12	Dec-12	315,000	280,000	—		—		—		—		—		—		—
	(7)						UKNS	ATP Oil & Gas	Dec-12	Apr-13	335,000	315,000
	(6), (7)						UKNS	ATP Oil & Gas	Apr-13	Feb-15	318,000	335,000
Sedco 712		semi		1983	1,600	25,000	UKNS			Stacked			—		—		—		—		—		—		—
Sedco 714	(7)	semi		1983/1997	1,600	25,000	UKNS	Total	Jun-11	Dec-12	256,000	256,000	—		—		—		—		—		—		—
							UKNS	Total	Dec-12	Dec-13	398,000	256,000
GSF Grand Banks	(6), (8), (13), (25)	semi		1984	1,500	25,000	Canada	Husky	Jan-11	Jan-13	297,000	356,000	—		—		—		—		—		—		35
Actinia		semi		1982	1,500	25,000	India	ONGC	Jun-12	Jul-15	190,000	222,000	91		19		—		—		—		—		—
Sedco 601		semi		1983	1,500	25,000	Malaysia			Stacked			—		—		—		—		—		—		—
Sedneth 701	(7)	semi		1972/1993	1,500	25,000	Nigeria	NPDC	Sep-12	Sep-13	311,000	275,000	—		8		—		—		—		—		—
Transocean Winner	(6), (7)	semi		1983	1,500	25,000	NNS	Lundin	Apr-10	Oct-12	491,000	390,000	—		—		—		—		—		—		—
	(6), (7)						NNS	Marathon	Oct-12	Oct-13	460,000	491,000
Transocean Searcher	(6), (7), (25)	semi		1983/1988	1,500	25,000	NNS	BG	Jun-12	Jun-15	398,000	447,000	—		—		—		—		83		—		—
Transocean Prospect	(7), (17)	semi		1983/1992	1,500	25,000	UKNS	Nexen	Jun-11	Feb-13	247,000	N/A	87		5		—		—		—		—		—
	(7)						UKNS	Nexen	Feb-13	Aug-13	254,000	247,000
	(6), (7)						UKNS	Conoco Phillips	Feb-14	Oct-14	408,000	254,000
							UKNS	Conoco Phillips	Oct-14	Feb-15	378,000	408,000
J.W. McLean		semi		1974/1996	1,250	25,000	UKNS			Stacked			—		—		—		—		—		—		—
Sedco 704	(7), (25)	semi		1974/1993	1,000	25,000	UKNS	Chevron	Jun-12	Nov-12	309,000	308,000	—		—		—		80		40		—		—
	(7)						UKNS	Chevron	Nov-12	May-13	337,000	309,000
	(6), (7)						UKNS	Maersk	May-13	Apr-15	357,000	337,000
										Total Estimated Days Out of Service			279		59		13		219		173		191		165
										Estimated Average Contract Dayrate(5)			$	299,000	$	292,000	$	294,000	$	306,000	$	311,000	$	324,000	$	327,000


				Yr. (1)	Water	Drilling			Estimated	Estimated	Dayrate on Current	Dayrate on Previous	Estimated Out of Service Days (4)						Estimated Out of Service Days (4)
	Footnote	Floater	Dynamically	Entered	Depth	Depth			Contract	Expiration	Contract (3)	Contract (3)	2012						2013
Rig Type/Name	References	Type	Positioned	Service	(Feet)	(Feet)	Location	Customer	Start Date (2)	Date (2)	(Dollars)	(Dollars)	Q2		Q3		Q4		Q1		Q2		Q3		Q4
High Specification Jackups (9)
GSF Constellation I	(6)			2003	400	30,000	Indonesia	Total	Sep-12	Dec-15	150,000	140,000	—		17		70		—		—		—		28
GSF Constellation II				2004	400	30,000	Egypt	Pharonic Petroleum Company	Feb-10	Oct-12	109,000	194,000	—		—		61		1		—		—		—
	(6)						Gabon	Total	Oct-12	Jun-15	160,000	109,000
GSF Galaxy I	(7)			1991/2001	400	30,000	UKNS	Nexen	Jul-12	Jul-13	133,000	N/A	91		20		—		—		—		—		—
GSF Galaxy II	(7)			1998	400	30,000	UKNS	GDF Suez	Jul-11	Oct-12	169,000	N/A	—		—		—		—		—		30		90
	(7)						UKNS	GDF Suez	Oct-12	Aug-13	192,000	169,000
	(7)						UKNS	GDF Suez	Aug-13	Mar-14	212,000	192,000
	(7)						UKNS	GDF Suez	Mar-14	Nov-14	220,000	212,000
GSF Galaxy III	(6), (7)			1999	400	30,000	UKNS	Nexen	Jan-12	Jul-13	150,000	109,000	—		—		—		—		—		—		—
	(7)						UKNS	Nexen	Jul-13	Apr-14	220,000	150,000
GSF Magellan				1992	350	30,000	Nigeria	ExxonMobil	Dec-11	Nov-12	143,000	N/A	—		—		—		—		—		—		—
GSF Monarch	(6)			1986	350	30,000	Denmark	Maersk Oil	Jul-11	Sep-13	92,000	N/A	—		65		4		—		—		—		60
GSF Monitor	(13)			1989	350	30,000	Nigeria	NPDC	Sep-12	Oct-13	153,000	118,000	—		17		28		—		—		—		60
Transocean Honor	(6)			2012	400	30,000	Angola	Chevron	May-12	May-15	149,000	N/A	—		—		—		—		—		—		—
										Total Estimated Days Out of Service			91		119		163		1		—		30		238
										Estimated Average Contract Dayrate(5)			$	129,000	$	148,000	$	158,000	$	159,000	$	156,000	$	154,000	$	157,000

Standard Jackups (32) - See Footnote 12
Trident IX				1982	400	21,000	Malaysia	Petrofac	Jul-11	May-13	114,000	N/A	—		—		—		7		—		—		—
GSF Adriatic IX				1981	350	25,000	Nigeria	Afren	Aug-12	Aug-13	137,000	100,000	4		—		—		—		—		—		—
GSF Adriatic X				1982	350	30,000	Nigeria	Addax Petroleum	Jul-12	Jan-13	130,000	110,000	—		—		—		—		—		—		31
GSF Key Manhattan				1980	350	25,000	Italy	Eni	Apr-10	Mar-13	137,000	N/A	—		—		—		—		12		—		—
							Italy	Eni	Mar-13	Apr-15	134,000	137,000
GSF Baltic	(6), (7)			1983	375	25,000	Nigeria	ExxonMobil	Jun-12	Jun-13	155,000	100,000	8		21		—		—		—		—		—
C.E. Thornton				1974	300	25,000	India	ONGC	May-12	May-15	83,000	N/A	50		—		—		—		—		—		—
F.G. McClintock				1975	300	25,000	India	ONGC	Apr-12	Apr-15	83,000	N/A	28		—		—		—		—		2		26
GSF Compact Driller	(17)			1992	300	25,000	Thailand	Chevron	Feb-12	Apr-13	103,000	100,000	—		—		7		—		—		42		—
							Thailand	Chevron	Apr-13	Jul-13	135,000	103,000
							Thailand	Chevron	Jul-13	Aug-14	129,000	135,000
GSF Galveston Key				1978	300	25,000	Malaysia	Petrofac	Jul-12	Jan-14	119,000	116,000	36		33		—		—		—		—		—
GSF Key Gibraltar	(17)			1976/1996	300	25,000	Thailand	Chevron	Jul-12	Oct-12	125,000	112,000	—		—		—		—		—		—		—
							Thailand	Chevron	Oct-12	Jul-13	95,000	125,000
GSF Key Hawaii				1982	300	25,000	Vietnam	Petrovietnam	Jun-12	Mar-13	131,000	111,000	—		6		—		—		—		—		—
GSF Main Pass I				1982	300	25,000	Saudi Arabia	Saudi Aramco	Jun-11	Oct-14	73,000	164,000	—		18		1		—		86		4		—
GSF Main Pass IV				1982	300	25,000	Saudi Arabia	Saudi Aramco	Jul-11	Oct-14	73,000	164,000	45		—		—		—		—		—		—
GSF Parameswara				1983	300	20,000	Indonesia	Total	Nov-09	Dec-12	122,000	168,000	—		—		—		60		—		—		—
							Indonesia	Total	Mar-13	Mar-15	136,000	122,000
Harvey H. Ward				1981	300	25,000	Indonesia	Pertamina	Nov-11	Nov-13	97,000	N/A	—		—		—		—		—		—		31
J.T. Angel				1982	300	25,000	India	ONGC	May-10	May-13	65,000	N/A	—		—		—		—		28		—		90
Randolph Yost				1979	300	25,000							61		92		61		11		19		—		—
Ron Tappmeyer				1978	300	25,000	India	ONGC	Jun-10	Jun-13	65,000	64,000	—		—		20		—		—		—		90
Trident 15	(18)			1982	300	25,000	Thailand	Chevron	Aug-12	Sep-13	100,000	110,000	6		—		—		—		—		—		—
							Thailand	Chevron	Sep-13	Dec-15	139,000	100,000
Trident 16				1982	300	25,000	Thailand	Chevron	Apr-12	Feb-13	100,000	118,000	36		—		—		—		—		—		—
							Thailand	Chevron	Feb-13	Mar-13	133,000	100,000
Trident II				1977/1985	300	25,000	India	ONGC	Mar-10	Apr-15	78,000	140,000	35		—		—		—		—		—		—
Trident VIII	(21)			1981	300	21,000	Gabon	Perenco	Oct-11	Mar-13	96,000	85,000	—		—		—		—		—		3		12
Trident XII				1982/1992	300	25,000	India	ONGC	May-10	May-13	65,000	140,000	19		13		10		—		—		—		90
Trident XIV	(6)			1982/1994	300	25,000	Angola	Chevron	Jun-12	Jun-14	116,000	102,000	89		—		—		—		—		—		—
GSF High Island II				1979	270	20,000	Saudi Arabia	Saudi Aramco	Jul-11	Oct-14	73,000	164,000	26		—		—		—		20		—		—
GSF High Island IV				1980/2001	270	20,000	Saudi Arabia	Saudi Aramco	May-07	Sep-14	73,000	107,000	—		—		—		—		—		—		—
GSF High Island IX				1983	250	20,000	Saudi Arabia	Saudi Aramco	Oct-12	Aug-15	117,000	N/A	91		92		44		—		—		—		—
GSF High Island VII				1982	250	20,000	Nigeria	Addax Petroleum	May-12	Nov-12	113,000	110,000	18		—		—		—		—		—		—
							Nigeria	Shebah	Nov-12	Nov-13	137,000	125,000
GSF Rig 105				1975	250	20,000	Egypt	Petrobel	Mar-12	Feb-13	65,000	112,000	—		—		12		—		—		—		—
GSF Rig 124				1980	250	20,000	Egypt	Petrobel	Dec-11	Dec-12	63,000	N/A	—		—		—		28		—		—		—
GSF Rig 141				1982	250	20,000	Egypt	GUPCO	Jul-11	Jul-13	55,000	N/A	—		—		25		—		—		—		—
Transocean Comet				1980	250	20,000	Egypt	GUPCO	Sep-09	Nov-12	50,000	112,000	5		9		—		—		—		—		8
										Total Estimated Days Out of Service			557		284		180		106		165		51		378
										Estimated Average Contract Dayrate(5)			$	91,000	$	92,000	$	96,000	$	96,000	$	101,000	$	102,000	$	104,000

Yr. (1)

Water

Drilling

Estimated

Dayrate on
Current

Dayrate on
Previous

Estimated Out of Service Days (4)

Footnote

Floater

Dynamically

Entered

Depth

Contract

Expiration

Contract (3)

2012

2013

Rig Type/Name

References

Type

Positioned

Service

(Feet)

Location

Customer

Start Date (2)

Date (2)

(Dollars)

Swamp Barges (1) - See Footnote 12

Hibiscus

(6), (15)

1979/1993

20,000

Indonesia

Total

Oct-07

Dec-12

74,000

—

Fixed-Price Options (10)

High Specification Floater: Ultra-Deepwater

Deepwater Expedition

ship

1999

8,500

30,000

TBA

Nov-14

Jul-15

695,000

650,000

TBA

Jul-15

Mar-16

695,000

TBA

Mar-16

Nov-16

695,000

High Specification Floater: Harsh Environment

Transocean Barents

(6), (7), (23)

semi

2009

10,000

30,000

NNS

DNO

Oct-14

Jul-16

560,000

560,000

Transocean Spitsbergen

(6), (7), (22)

semi

2010

10,000

30,000

NNS

Statoil

Jul-15

Jul-17

542,000

533,000

Transocean Leader

(6), (7), (25)

semi

1987/1997

4,500

25,000

NNS

Statoil

Mar-15

Mar-16

413,000

400,000

Transocean Arctic

(6), (7)

semi

1986

1,650

25,000

NNS

Rig Management Norway

Feb-14

Aug-14

423,000

410,000

NNS

Rig Management Norway

Nov-14

Mar-15

423,000

410,000

Midwater Floaters

Transocean Winner

(6), (7)

semi

1983

1,500

25,000

NNS

Marathon

Oct-13

Oct-14

460,000

447,000

High Specification Jackups

GSF Magellan

1992

350

30,000

Nigeria

ExxonMobil

Nov-12

May-13

160,000

143,000

GSF Constellation II

2004

400

30,000

Gabon

Total

Jun-15

Jun-16

160,000

109,000

Standard Jackups

Trident VIII

(21

)

1981

300

21,000

Gabon

Perenco

Mar-13

Sep-13

Footnote 21

96,000

Revenue Efficiency

Revenue Efficiency is defined as actual contract drilling revenue divided by the highest amount of total contract drilling revenue which could have been earned during the relevant period(s) expressed as a percentage. Revenue Efficiency measures how much revenue we have earned against our maximum potential revenue per the contract. Revenue Efficiency does not apply during Out of Service Days (Shipyard, Mobilizations, Demobilizations, Contract Preparation). The following table has been restated for Caspian Sea discontinued operations.

	Q2 2012 Actual		Q1 2012 Actual		Q4 2011 Actual		Q3 2011 Actual		Q2 2011 Actual		Q1 2011 Actual		Q4 2010 Actual		Q3 2010 Actual
Ultra Deepwater	92.2	%	89.4	%	89.5	%	86.4	%	89.3	%	85.3	%	86.1	%	86.5	%
Deepwater	92.1	%	83.2	%	88.1	%	87.7	%	93.9	%	88.2	%	88.6	%	90.1	%
Harsh Environment Floaters	98.1	%	97.8	%	98.0	%	94.4	%	98.4	%	99.2	%	96.1	%	96.4	%
Midwater Floaters	87.4	%	90.8	%	94.2	%	90.8	%	91.9	%	93.6	%	85.0	%	96.2	%
High Specification Jackups	94.5	%	92.5	%	94.3	%	97.3	%	95.6	%	95.1	%	97.7	%	93.3	%
Standard Jackups	97.4	%	97.9	%	96.4	%	98.2	%	98.4	%	97.7	%	98.9	%	96.4	%
Others	99.4	%	97.3	%	98.6	%	99.5	%	97.6	%	99.0	%	96.1	%	99.6	%
Total Fleet	92.5	%	90.6	%	91.9	%	89.5	%	92.1	%	90.0	%	88.7	%	91.8	%

Estimated Contract Drilling Revenue can be calculated as:

Paid Days on Contract * Average Contract Dayrate * Revenue Efficiency

		Transocean Ltd. (NYSE: RIG), (SIX: RIGN) Fleet Status Report
Updated: October 17, 2012
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 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 May 4, 2011 will be reported as commencing in April 2011) 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 May 24, 2011 will be reported as commencing in May 2011). 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 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)		The out of service time represents those days where a rig is scheduled to be out of service and not be available to earn an operating dayrate. Please refer to the “Out of Service Days (Shipyards, Mobilizations, Demobilizations, Contract Preparation)” section of the Disclaimers & Definitions for a full description.
(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)		Reflects the current contracted dayrate which could reflect prior cost escalations and could change in the future due to further cost escalations.
(7)		Reflects the current contracted dayrate which is comprised of a foreign currency component and which could change due to foreign exchange adjustments.
(8)		Current contract provides for a bonus incentive opportunity not reflected in the stated current contract dayrate.
(9)		For the period of time that this rig is contracted to Applied Drilling Technology International, the drilling management services division of the company’s U.K. operating subsidiary, or Applied Drilling Technology Inc., the company’s U.S. drilling management services subsidiary, accounting rules require that we eliminate the revenues and costs related to those contracts from the contract drilling segment of the consolidated statement of operations. Revenues from turnkey contracts will be recognized in other revenues and are contingent upon successful completion of the well program.
(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)		The contract is expected to start in the quarter indicated. Factors that could influence the contract start date include shipyard delivery, customer acceptance, and mobilization to operating location, among others.
(12)		In the third quarter of 2012, the company reclassified 32 Standard Jackups and one swamp barge associated with Shelf Drilling as discontinued operations, including the GSF Baltic, which has been reclassified as a standard jackup. An additional 12 stacked Standard Jackups have been classified as held for sale: GSF Key Singapore, GSF Adriatic VI, GSF Adriatic VIII, D.R. Stewart, GSF Adriatic I, GSF Adriatic V, GSF Rig 134, Interocean III, Trident IV-A, GSF High Island V, GSF Rig 127 and Trident VI.
(13)		The rig’s planned out of service time extends into the first quarter of 2014: Transocean John Shaw - 59 days, GSF Grand Banks - 90 days, Paul B. Loyd, Jr. - 39 days and GSF Monitor - 60 days.
(14)		Until August 2012, the contract dayrate was $469,000, subject to cost escalation. The dayrate for the remainder of the contract is linked to the standard West Texas Intermediate crude oil price with a floor of $40 per barrel resulting in a contract dayrate of $400,000 and a ceiling of $70 per barrel resulting in a contract dayrate of $500,000, subject to cost escalation.
(15)		The rig is owned by a joint venture in which the company owns less than a 100 percent interest. Dayrate reflects 100 percent of the contract rate.
(16)		The customer may elect to have the operating dayrate for the last five years of the contract fluctuate based on crude oil price with a floor of $458,250 corresponding to a crude oil price of less than or equal to $50 per barrel, and a ceiling of $558,250 corresponding to a crude oil price of $100 per barrel or greater.
(17)		Dayrate is fixed for first 6 months then subject to quarterly adjustment based on market dayrates within specific parameters.
(18)		Dayrate subject to annual adjustment based on market dayrates within specific parameters.
(19)		Dayrate excludes tax amounts, to be determined, for which Transocean will be reimbursed.
(20)		While the customer has the option to add any out of service days to the end of the contract, the Estimated Expiration Date does not reflect any extension due to this option until actually exercised by the customer.
(21)		The customer has the option to extend the contract for an additional six month period at any time prior to October 30, 2012 at a dayrate with a floor of $85,000 and a ceiling of $130,000, to be mutually agreed upon between us and the customer at the time of exercise.
(22)		Dayrate excludes additional premiums for parallel operations at well centers, dynamic position operations and operations in water depths greater than 500 meters.
(23)		Dayrate excludes additional premiums for parallel operations at well centers, dynamic position operations and HPHT operations. Reduced dayrate will apply up to a maximum of 200 days for operation in water depths less or equal to 500 meters.
(24)		The contract guarantees a minimum of 240 days at this dayrate which applies for drilling HPHT wells. The dayrate will become $265,000 if the rig drills standard wells.
(25)		As a result of the requirement for third party certification of well control equipment on rigs operating in the U.S. Gulf of Mexico, and potential future requirements imposed by our customers, other regulators, and industry standards, Transocean preemptively embarked on a well control equipment certification program in 2010. We have acquired third party certification of well control equipment on 40 of our 63 active floaters, including 23 of 27 of our ultra deepwater rigs. All of the rigs currently operating in the Gulf of Mexico have been certified to meet existing regulatory and customer requirements. Rigs that move between locations or customers may require additional well control equipment certification even if the rigs meet Transocean’s certification program, current customer or regulatory requirements. In 2012, the following floaters are planned to conduct extensive well control equipment overhaul during their out of service period: Sedco 707, Transocean Leader, GSF Explorer, Discoverer Seven Seas and GSF Rig 135. In 2013, the following floaters are planned to conduct extensive well control equipment overhaul during their out of service period: Sedco 702, Sedco 711, GSF Grand Banks, GSF Development Driller I, Transocean Searcher, Transocean Amirante, Transocean Legend, Transocean John Shaw, Paul B. Loyd, Sedco 704, Deepwater Millennium, and M.G. Hulme, Jr.
(26)		Construction of the Deepwater Asgard is expected to be completed in the first quarter of 2014 followed by sea trials and mobilization.

		Transocean Ltd. (NYSE: RIG), (SIX: RIGN) Fleet Status Report
Updated: October 17, 2012
Revisions Noted in Bold

Stacked Rigs

Rig Type/Name		Start Date
*Deepwater (3)*

Sedco 709		Prior to 2010
Transocean Richardson		3/15/2011
Sovereign Explorer		11/1/2010

*Midwater Floaters (7)*

Sedco 700		Prior to 2010
C. Kirk Rhein, Jr.		Prior to 2010
GSF Aleutian Key		1/9/2010
Sedco 703		Prior to 2010
Sedco 712		Prior to 2010
Sedco 601		4/9/2011
J.W. McLean		4/13/2011

Stacked and Idle rigs detailed above are not currently operating on contract. Start date denotes when rig commences idle or stacked status.

An “Idle” rig is between contracts, readily available for operations, and operating costs are typically at or near normal levels. A “Stacked” rig, on the other hand, is 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 30 to 60 days following initiation of stacking.

Transocean Ltd. (NYSE: RIG), (SIX: RIGN) Fleet Status Report

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 Days (Shipyards, Mobilizations, Demobilizations,Contract Preparation). Changes in estimated out of service time are noted where changes in the time Transocean anticipates that a rig is scheduled to be out of service and not be available to earn an operating dayrate have changed by a period of 15 days or longer for all rig classifications since the previously issued Monthly Fleet Update Summary or Comprehensive Fleet Status Report. The changes to estimated out of service time included in this Fleet Status 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 Monthly Fleet Updates and Comprehensive Fleet Status Reports, as applicable.

Contract Preparation refers to periods during which the rig is undergoing modifications or upgrades as a result of contract requirements. Shipyards refers to periods during which the rig is out of service as a result of other scheduled shipyards, surveys, repairs, regulatory inspections or other scheduled service or work on the rig.

In some instances such as certain mobilizations, demobilizations, 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 project, although such compensation is not typically significant in relation to the revenues generated by the dayrates we charge our customers. When mobilization or demobilization occurs during a contract period, we recognize revenues as earned. In instances where mobilization or demobilization time occurs before or between the start of a contract period, the stated estimated contract start date represents the expected commencement date for the primary contract term of the drilling project and the point at which we expect to begin recognizing revenues.

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 Classification. Transocean uses a rig classification for its semisubmersible rigs and drillships to reflect the company’s strategic focus on the ownership and operation of premium, high specification floating rigs. The rig classification “High Specification Floaters” is comprised of “Ultra-Deepwater” which refers to the latest generation of semisubmersible rigs and drillships possessing the latest technical drilling capabilities and the ability to operate in water depths equal to or greater than 7,500 feet, “Deepwater” which refers to semisubmersible rigs and drillships that possess the ability to drill in water depths equal to or greater than 4,500 feet, and “Harsh Environment” comprised of seven of the company’s premium harsh environment rigs, the semisubmersibles Transocean Barents, Transocean Spitsbergen, Henry Goodrich, Transocean Leader, Paul B. Loyd, Jr., Transocean Arctic and Polar Pioneer. The category titled “Midwater Floaters” represents semisubmersible rigs and drillships that possess the ability to drill in water depths of up to 4,499 feet. The jackup fleet is subdivided into two categories; “High Specification” which consists of harsh environment and high performance jackups and “Standard”.

Stacking. An “Idle” rig is between contracts, readily available for operations, and operating costs are typically at or near normal levels. A “Stacked” rig, on the other hand, is 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 30 to 60 days following initiation of stacking.

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