Transocean Partners (RIGP) 8-K Transocean Partners LLC Reports Second Quarter 2016 Results

Exhibit 99.1

Transocean Partners LLC Reports Second Quarter 2016 Results

· Net income attributable to controlling interest was $36 million, $0.52 per unit, compared with net income attributable to controlling interest of $31 million, $0.45 per unit, in the previous quarter;

· Cash flows from operating activities were $95 million, up from $78 million in the first quarter of 2016;

· Distributable cash flow attributable to controlling interest was $36 million, compared with $34 million in the prior quarter;

· A quarterly distribution of $0.3625 per unit has been declared;

· Fleet revenue efficiency(1) was 99.7 percent, up from 92.8 percent in the previous quarter;

· Fleet utilization(2) was 100 percent, unchanged from the first quarter of 2016;

· Revenues were $155 million, up from $144 million in the prior quarter;

· Operating and maintenance expense was $53 million, down from $55 million in the previous quarter; and

· The Annual Effective Tax Rate(3) was 5.4 percent, unchanged from the first quarter of 2016.

LONDON—August 3, 2016—Transocean Partners LLC (NYSE: RIGP) today reported net income attributable to controlling interest for the three months ended June 30, 2016, of $36 million, or $0.52 per unit.

For the three months ended June 30, 2015, the company reported net income attributable to controlling interest of $35 million, or $0.51 per unit.

Distributable cash flow attributable to controlling interest was $36 million, compared with $34 million in the first quarter of 2016. For the three months ended June 30, 2016, a quarterly distribution of $0.3625 per unit, or approximately $25 million based upon the number of currently outstanding units, has been declared.

Revenues increased $11 million sequentially to $155 million due primarily to higher revenue efficiency on the Discoverer Clear Leader and the Discoverer Inspiration.

Operating and maintenance expense decreased $2 million sequentially to $53 million due largely to the expiration of the non-cash patent royalty expense that was scheduled to expire during the quarter. This decrease was partially offset by higher overhead costs.

General and administrative expense was $7 million, compared to $6 million in the prior quarter.

The company’s Effective Tax Rate (4) was 5.7 percent, compared to 5.8 percent in the first quarter of 2016. The Annual Effective Tax Ratewas 5.4 percent, unchanged from the previous quarter.

Earnings Conference Call Cancelled

The second quarter 2016 earnings conference call previously scheduled for Thursday, August, 4, 2016, was cancelled following the August 1, 2016 announcement of the merger agreement with Transocean.

Non-GAAP Financial Measures

Distributable cash flow, EBITDA, adjusted EBITDA and adjusted net income are non-GAAP financial measures; reconciliations of the non-GAAP measures to the most directly comparable GAAP measures are provided in the accompanying schedules and are displayed in quantitative schedules on the company’s website at: www.transoceanpartners.com.

About Transocean Partners

Transocean Partners was formed as a growth-oriented limited liability company by Transocean Ltd. to own, operate and acquire modern, technologically advanced offshore drilling rigs. Transocean Partners’ assets consist of 51 percent interests in subsidiary companies that own and operate three ultra-deepwater drilling rigs.

For more information about Transocean Partners, please visit: www.transoceanpartners.com.

Forward-Looking Statements

The statements described in this press release that are not historical facts are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. These statements contain words such as "possible," "intend," "will," "if," "expect" or other similar expressions. Forward-looking statements are based on management’s current expectations and assumptions, and are subject to inherent uncertainties, risks and changes in circumstances that are difficult to predict. As a result, actual results could differ materially from those indicated in these forward-looking statements. Factors that could cause actual results to differ materially include, but are not limited to, unit repurchases and the timing of the repurchases, the distribution and timing of distribution payments, the securities markets generally, the impact of adverse market conditions affecting the business of Transocean Partners, utilization, downtime and other aspects of Transocean Partners’ drilling rigs, adverse changes in laws including with respect to tax and regulatory matters, changes in tax estimates, impairment of goodwill, asset impairments, operating hazards and delays, risks associated with international operations, actions by customers and other third parties, the prices of oil and gas, capital markets and other factors, including those and other factors discussed in  Transocean Partners’ Annual Report on Form 10-K for the year ended December 31, 2015, and in Transocean Partners’ 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 the other consequences of such a development worsen), or should underlying assumptions prove incorrect, actual results may vary materially from those indicated or expressed or implied by such forward-looking statements. You should not place undue reliance on forward-looking statements. Each forward-looking statement speaks only as of the date of the particular statement, Transocean Partners undertakes no obligation to publicly update or revise any forward-looking statements to reflect events or circumstances that occur, or which Transocean Partners becomes aware of, after the date hereof, except as otherwise may be required by law.

Notes

(1) Revenue efficiency is defined as actual contract drilling revenues for the measurement period divided by the maximum revenue calculated for the measurement period, expressed as a percentage. Maximum revenue is defined as the greatest amount of contract drilling revenues the drilling unit could earn for the measurement period, excluding amounts related to incentive provisions. See the accompanying schedule entitled "Revenue Efficiency."

(2) Rig utilization is defined as the total number of operating days divided by the total number of rig calendar days in the measurement period, expressed as a percentage.

(3) Annual Effective Tax Rate is defined as income tax expense excluding various discrete items (such as changes in estimates and tax on items excluded from income before income taxes), divided by income before income tax expense, excluding gains and losses on sales and similar items pursuant to the accounting standards for income taxes and estimating the annual effective tax rate. See the accompanying schedule entitled "Supplemental Effective Tax Rate Analysis."

(4) Effective Tax Rate is defined as income tax expense divided by income before income taxes. See the accompanying schedule entitled "Supplemental Effective Tax Rate Analysis."

Analyst Contacts:

Bradley Alexander

+1 713-232-7515

Diane Vento

+1 713-232-8015

Media Contact:

Pam Easton

+1 713-232-7647

TRANSOCEAN PARTNERS LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In millions, except per unit data)

(Unaudited)

	Three months ended				Six months ended
	June 30,				June 30,
	2016		2015		2016		2015
Operating revenues
Contract drilling revenues	$	152	$	157	$	293	$	293
Other revenues		3		4		6		8
		155		161		299		301
Costs and expenses
Operating and maintenance		53		60		108		118
Depreciation		17		17		34		34
General and administrative		7		6		13		11
		77		83		155		163
Loss on impairment		—		—		—		(67)
Loss on disposal of assets		—		(1)		—		(1)
Operating income		78		77		144		70
Other income
Interest income		—		1		1		2
Interest expense		(1)		(1)		(1)		(1)
Income before income tax expense		77		77		144		71
Income tax expense		4		4		8		8
Net income		73		73		136		63
Net income attributable to noncontrolling interest		37		38		69		34
Net income attributable to controlling interest	$	36	$	35	$	67	$	29
Earnings per unit—basic
Earnings per common unit	$	0.52	$	0.51	$	0.97	$	0.43
Earnings per subordinated unit	$	0.52	$	0.51	$	0.97	$	0.43
Earnings per unit—diluted
Earnings per common unit	$	0.52	$	0.51	$	0.97	$	0.43
Earnings per subordinated unit	$	0.52	$	0.51	$	0.97	$	0.43
Weighted-average units outstanding—basic
Common units		41		41		41		41
Subordinated units		28		28		28		28
Weighted-average units outstanding—diluted
Common units		41		41		41		41
Subordinated units		28		28		28		28

TRANSOCEAN PARTNERS LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(In millions, except unit data)

(Unaudited)

	June 30,		December 31,
	2016		2015
Assets
Cash and cash equivalents	$	171	$	159
Accounts receivable		108		115
Accounts receivable from affiliates		—		1
Materials and supplies, net of allowance for obsolescence of $6 at June 30, 2016 and December 31, 2015		38		34
Prepaid assets		12		7
Total current assets		329		316
Property and equipment		2,313		2,296
Less accumulated depreciation		(440)		(401)
Property and equipment, net		1,873		1,895
Deferred income taxes, net		7		10
Other assets		8		10
Total assets	$	2,217	$	2,231
Liabilities and equity
Accounts payable to affiliates	$	60	$	51
Deferred revenues		7		15
Other current liabilities		1		2
Total current liabilities		68		68
Long-term tax liability		5		3
Drilling contract intangible liability		6		14
Other long-term liabilities		1		1
Total long-term liabilities		12		18
Commitments and contingencies
Common units, 40,914,962 and 41,287,810 issued and outstanding at June 30, 2016 and December 31, 2015, respectively		769		757
Subordinated units, 27,586,207 issued and outstanding at June 30, 2016 and December 31, 2015		515		505
Total members’ equity		1,284		1,262
Noncontrolling interest		853		883
Total equity		2,137		2,145
Total liabilities and equity	$	2,217	$	2,231

TRANSOCEAN PARTNERS LLC AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In millions)

(Unaudited)

	Six months ended
	June 30,
	2016		2015
Cash flows from operating activities
Net income	$	136	$	63
Adjustments to reconcile to net cash provided by operating activities
Amortization of drilling contract intangible		(8)		(7)
Depreciation		34		34
Patent royalties expense		8		12
Loss on impairment		—		67
Deferred income taxes		3		2
Other, net		1		—
Changes in deferred revenues, net		(8)		(7)
Changes in deferred costs, net		2		—
Changes in operating assets and liabilities		5		13
Net cash provided by operating activities		173		177
Cash flows from investing activities
Payments to affiliates for capital expenditures		(12)		(10)
Proceeds from affiliates for disposal of assets, net		3		4
Net cash used in investing activities		(9)		(6)
Cash flows from financing activities
Distributions of available cash to unitholders		(50)		(50)
Distributions to holder of noncontrolling interests		(99)		(40)
Payments to repurchase common units		(3)		—
Contributions for parent indemnification of lost revenues		—		10
Net cash used in financing activities		(152)		(80)
Net increase in cash and cash equivalents		12		91
Cash and cash equivalents at beginning of period		159		86
Cash and cash equivalents at end of period	$	171	$	177

Transocean Partners LLC and Subsidiaries

Revenue Efficiency(1)

	2Q 2016		1Q 2016		2Q 2015		FY 2015		FY 2014
Discoverer Clear Leader	101.8	%	83.3	%	99.2	%	98.7	%	88.8	%
Discoverer Inspiration	103.5	%	96.5	%	101.4	%	82.5	%	97.4	%
Development Driller III	92.3	%	99.9	%	107.8	%	101.1	%	98.3	%
Total fleet	99.7	%	92.8	%	102.4	%	93.8	%	94.6	%

(1) Revenue efficiency is defined as actual contract drilling revenues for the measurement period divided by the maximum revenue calculation for the measurement period, expressed as a percentage.  Maximum revenue is defined as the greatest amount of contract drilling revenues the drilling unit could earn for the measurement period, excluding amounts related to incentive provisions.

Transocean Partners LLC and Subsidiaries

Supplemental Effective Tax Rate Analysis

(In US$ millions, except tax rates)

	Three months ended									Six months ended
	June 30,			March 31,			June 30,			June 30,			June 30,
	2016			2016			2015			2016			2015
Income (loss) before income taxes	$	77		$	67		$	77		$	144		$	71
Add back (subtract):
Loss on impairment of goodwill		—			—			—			—			67
Adjusted income before income taxes	$	77		$	67		$	77		$	144		$	138
Income tax (benefit) expense		4			4			4			8			8
Add back (subtract):
Changes in estimates (1)		—			—			—			—			—
Adjusted income tax expense	$	4		$	4		$	4		$	8		$	8
Effective Tax Rate (2)		5.7	%		5.8	%		5.8	%		5.8	%		12.0
Annual Effective Tax Rate (3)		5.4	%		5.4	%		5.8	%		5.4	%		6.2

(1) Our estimates change as we file tax returns, settle disputes with tax authorities or become aware of other events and include changes in (a) deferred taxes, (b) valuation of allowances on deferred taxes and (c) other tax liabilities.

(2) Effective Tax Rate is income tax expense for continuing operations, divided by income from continuing operations before income taxes.

(3) Annual Effective Tax Rate is income tax expense for continuing operations, excluding various discrete items (such as changes in estimates and tax on items excluded from income before income taxes) divided by income from continuing operations before income tax expense excluding gains and losses on sales and similar items pursuant to the accounting standards for income taxes and estimating the annual effective tax rate.

Transocean Partners LLC and Subsidiaries

Non-GAAP Financial Measures and Reconciliations

Distributable Cash Flow

(in US$ millions, except coverage ratio)

									Trailing		Year
	Three months ended								12		ended
	06/30/16		03/31/16		12/31/15		09/30/15		months		12/31/15
Net income (loss)	$	73	$	63	$	71	$	(261)	$	(54)	$	(127)
Plus:
Income tax expense		4		4		5		1		14		14
Interest income		—		(1)		—		—		(1)		(2)
Interest expense		1		—		—		—		1		1
Depreciation expense		17		17		17		17		68		68
EBITDA		95		83		93		(243)		28		(46)
Plus:
Recognition of prior certification costs and license fees		—		1		1		1		3		3
Recognition of patent royalties expense		2		6		6		5		19		23
Loss on impairment of goodwill		—		—		—		289		289		356
Less:
Recognition of drilling contract intangible		4		4		4		4		16		15
Recognition of pre-operating revenues		4		4		4		4		16		19
Adjusted EBITDA		89		82		92		44		307		302
Plus:
Planned out-of-service operating and maintenance expense		—		1		1		4		6		10
Cash proceeds from pre-operating revenues associated with long-term receivables		3		4		4		4		15		17
Less:
Estimated maintenance and replacement capital expenditures		17		17		16		17		67		66
Cash interest income, net		(1)		—		—		—		(1)		(2)
Cash income taxes		3		1		2		2		8		9
Distributable Cash Flow		73		69		79		33		254		256
Distributable cash flow attributable to noncontrolling interest		37		35		41		17		130		131
Distributable cash flow attributable to controlling interest	$	36	$	34	$	38	$	16	$	124	$	125
Aggregate declared distribution to unitholders	$	25	$	25	$	25	$	25	$	100	$	100
Distribution coverage ratio		1.44x		1.37x		1.51x		0.64x		1.24x		1.25x

Transocean Partners LLC and Subsidiaries

Non-GAAP Financial Measures and Reconciliations

Distributable Cash Flow

(in US$ millions, except coverage ratio)

									Trailing		Year
	Three months ended								12		ended
	06/30/16		03/31/16		12/31/15		09/30/15		months		12/31/15
Net cash provided by operating activities	$	95	$	78	$	68	$	67	$	308	$	312
Plus:
Changes in operating assets and liabilities		(7)		2		21		(22)		(6)		(14)
Changes in deferred revenues, net		4		4		5		4		17		16
Changes in deferred costs, net		(1)		(1)		(1)		(1)		(4)		(2)
Interest income, net of interest expense		1		(1)		—		—		—		(1)
Income tax expense, current		2		3		—		3		8		9
Recognition of drilling contract intangible		4		4		4		4		16		15
Recognition of patent royalties expense		(2)		(6)		(6)		(5)		(19)		(23)
Loss on impairment of goodwill		—		—		—		(289)		(289)		(356)
Other, net		(1)		—		2		(4)		(3)		(2)
EBITDA		95		83		93		(243)		28		(46)
Plus:
Recognition of prior certification costs and license fees		—		1		1		1		3		3
Recognition of patent royalties expense		2		6		6		5		19		23
Loss on impairment of goodwill		—		—		—		289		289		356
Less:
Recognition of drilling contract intangible		4		4		4		4		16		15
Recognition of pre-operating revenues		4		4		4		4		16		19
Adjusted EBITDA		89		82		92		44		307		302
Plus:
Planned out-of-service operating and maintenance expense		—		1		1		4		6		10
Cash proceeds from pre-operating revenues associated with long-term receivables		3		4		4		4		15		17
Less:
Estimated maintenance and replacement capital expenditures		17		17		16		17		67		66
Cash interest income, net		(1)		—		—		—		(1)		(2)
Cash income taxes		3		1		2		2		8		9
Distributable Cash Flow		73		69		79		33		254		256
Distributable cash flow attributable to noncontrolling interest		37		35		41		17		130		131
Distributable cash flow attributable to controlling interest	$	36	$	34	$	38	$	16	$	124	$	125
Aggregate declared distribution to unitholders	$	25	$	25	$	25	$	25	$	100	$	100
Distribution coverage ratio		1.44x		1.37x		1.51x		0.64x		1.24x		1.25x

Transocean Partners LLC and Subsidiaries

Non-GAAP Financial Measures and Reconciliations

Adjusted Net Income and Adjusted Diluted Earnings Per Unit

(in US$ millions, except per unit data)

									YTD		QTD		QTD
									06/30/16		06/30/16		03/31/16
Adjusted Net Income
Net income attributable to controlling interest, as reported									$	67	$	36	$	31
Add back (subtract):
Discrete tax items and other, net										—		—		—
Net income, as adjusted									$	67	$	36	$	31
Adjusted Diluted Earnings Per Unit:
Diluted earnings per unit, as reported									$	0.97	$	0.52	$	0.45
Add back (subtract):
Discrete tax items and other, net										—		—		—
Diluted earnings per unit, as adjusted									$	0.97	$	0.52	$	0.45
	YTD		QTD		YTD		QTD		YTD		QTD		QTD
	12/31/15		12/31/15		09/30/15		09/30/15		06/30/15		06/30/15		03/31/15
Adjusted Net Income
Net income (loss) attributable to controlling interest, as reported	$	(71)	$	34	$	(105)	$	(134)	$	29	$	35	$	(6)
Add back (subtract):
Loss on impairment of goodwill attributable to controlling interest		182		—		182		148		34		—		34
Net income, as adjusted	$	111	$	34	$	77	$	14	$	63	$	35	$	28
Adjusted Diluted Earnings Per Unit:
Diluted earnings (loss) per unit, as reported	$	(1.02)	$	0.49	$	(1.52)	$	(1.94)	$	0.43	$	0.51	$	(0.09)
Add back (subtract):
Loss on impairment of goodwill attributable to controlling interest		2.62		—		2.63		2.13		0.49		—		0.50
Diluted earnings per unit, as adjusted	$	1.60	$	0.49	$	1.11	$	0.19	$	0.92	$	0.51	$	0.41