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1 www.riceenergy.com
Rice Midstream PartnersThird Quarter 2015 Supplemental Slides
November 5, 2015
2 www.riceenergy.com
RMP: High Growth MLP in Prolific Appalachian Basin
PA gas gathering system of 4.1 MMDth/d design capacity by YE2015̶ Oversized to accommodate future growth and
emerging PA Utica potential 3Q15 throughput of 671 MDth/d with 17% 3rd party Gathering throughput driven by SW PA technical
leaders̶ ~85% of 2015E estimated throughput from RICE
operated volumes, and ~15% from 3rd parties, primarily EQT
RMP constructing ~30 miles of gathering pipeline in 2015
RMP installing compression for RICE in 1H16 that will start generating revenue in 2016
RMP 2015E EBITDA of $60MM - $65MM(1)
2015 capex budget of $200MM(1) ($100MM gathering, $90MM compression, $5MM water and $5MM maintenance)
2 independent fresh water distribution systems with access to 15.9MMGPD of fresh water from Monongahela River, Ohio River & other regional sources
GATHERING SYSTEM INFORMATION12/31/14
DedicatedGross
Acreage
3Q 2015 Throughput
(MDth/d)2015E Capex
($MM)(1)
RMP 86,000 671 $200
ASSET OVERVIEW SYSTEM MAP
OHIO
Concentrated, Prolific Position to Drive Targeted 20% Distribution Growth
Greene
Washington
Fayette
Beaver
PENNSYLVANIA
WEST VIRGINIA
OH PA
WV
Belmont
Brooke
Legend
RMP Gathering Pipeline to be Constructed
RICE Acreage
RMP Gathering Pipeline
3rd Party Dedicated to RMPRICE Acreage Dedicated to 3rdParty
RMP Water PipelineRMP Water Pipeline to be ConstructedRMP Water Interconnects
WEST VIRGINIA
GPOR Water Dedication
OHIO
__________________________1. As of November 5, 2015.
3 www.riceenergy.com
RICE executed midstream JV LOI w/ GPOR to construct & operate gathering, compression & water services for their Utica acreage
ROFO on RICE’s OH gas gathering and compression assets In November, acquired RICE’s PA & OH water services business w/
access to ~16 MMGPD of fresh water sources in PA and OH for $200MM purchase price
Third quarter average daily throughput of 671 MDth/d 3% increase from 2Q average throughput
Increased distribution to $0.1935 / unit for 3Q15 Expect to increase distributions by 2% w/ targeted 4Q15 distribution of
$0.1965 / unit
$369MM liquidity with $100MM drawn under our revolving credit facility, pro forma for the water services business acquisition and PIPE proceeds
DCF coverage ratio of 1.25x for 3Q15 Cash flow driven by scalable dry gas throughput, complementary water
services business & protected w/ 100% fee based contracts
Ample liquidity and balance sheet strength positions RMP for continued growth through organic development and accretive acquisitions
Visible, top-tier distribution growth profile driven by disciplined and aligned sponsor, attractive drop-down candidates, and high-quality third party dedications
EXECUTION IS DRIVINGRAPID ORGANIC GROWTH
WELL-PROTECTED GROWTH &FINANCIAL FLEXIBILITY
ATTRACTIVE DROPDOWN POTENTIAL
PREDICTABLE CASHFLOW PROFILE
RMP Third Quarter 2015 Highlights
4 www.riceenergy.com
Successful Water Services Business Acquisition SummaryTRANSACTION OVERVIEW TRANSACTION HIGHLIGHTS
__________________________1. Excludes Gulfport midstream JV.2. Pro forma for close of water services business acquisition and private placement of common units for $175MM gross proceeds.3. Assumes fee of $0.06 per gallon in Pennsylvania and 11,000,000 gallons of water per well that utilize the fresh water delivery system based on a 7,000’ lateral.4. Assumes fee of $0.07 per gallon in Ohio and 16,900,000 gallons of water per well that utilize the fresh water delivery system based on a 9,000’ lateral.
Acquisition Complementary to Existing Assets and Accretive to DCF per Unit
Immediately accretive to distributable cash flow per unit & RMP increases 2015 DCF coverage to 1.15 – 1.2x
Integrates RMP’s gathering and compression business with water services business and enhances 3rd party opportunities
Volumetric tiers provide revenue and cash flow stability
Minimal future organic capital requirements for RICE development
RMP has $369 million pro forma(2) liquidity to fund future midstream development
RMP is acquiring Rice Energy’s water business for consideration of $200 million at closing plus a $25 million earn out upon achievement of certain increases to system capacities, less the capital expenditures, if any, invested to achieve such increases̶ $200 million purchase price funded with borrowings under RMP’s
RCF; RCF will partially repaid with proceeds from $175MM PIPE
WATER SERVICES AGREEMENTS OVERVIEWTiered Fresh Water Fee Pennsylvania OhioFresh Water Volumes (MMGal / Well)
Tier I 20
Fee ($ / Gallon)
Tier I $0.07 $0.08
Tier II $0.03 $0.04
Thereafter $0.01 $0.02
Expected Weighted Average Fee (3)(4) $0.06 $0.07
Produced Water Services Fee 2% of cost 2% of cost
ASSET OVERVIEW Fresh water distribution systems(1) & related facilities servicing Marcellus
and Utica completion operations in PA and OH̶ Includes the right to provide fresh water for completion operations
and to collect, recycle, and dispose of flowback and produced water for RICE in services area
̶ Access to 15.9 MMGPD of fresh water from the Monongahela River (PA), Ohio River (OH) & other regional sources in southwest PA and southeast OH
̶ 123 miles of pipeline and 143 million gallons of water impoundment capacity
As compared to trucking, water distribution systems are the more efficient way to transport fresh water for completions̶ Faster, more reliable completion jobs
Capable of delivering up to 3x more water per day, plus on-demand storage via impoundments
̶ Improved social responsibility Reduces truck traffic and resulting emissions, noise, road
repairs and safety incidents
5 www.riceenergy.com
__________________________1. Assumes fee of $0.06 per gallon and operating expense of $0.013 per gallon in Pennsylvania and 11,000,000 gallons of water per well that utilize the fresh water delivery system based on a 7,000’ lateral.2. Assumes fee of $0.07 per gallon and operating expense of $0.013 per gallon in Ohio and 16,900,000 gallons of water per well that utilize the fresh water delivery system based on a 9,000’ lateral.
Acquisition Assets – Integrated Water Services BusinessWATER SERVICES BUSINESS OVERVIEW WATER DISTRIBUTION SYSTEM MAP
Delivers fresh water to well pads for completions
Collects, recycles or disposes of flowback and produced water for RICE & 3rd parties
Volumetric fee structure to provide revenue & cash flow stability
PENNSYLVANIA & OHIO WATER SYSTEMS
PA trunk line substantially complete in 1Q15 and OH trunk line substantially complete in 3Q15
Trunk lines consist primarily of 24-30” polyethylene pipe & laterals consist of 18” polyethylene pipe
~100% of 2016E PA volumes expected to come from RICE & ~75% of 2016E OH volumes expected to come from RICE
PROJECTED FRESH WATER DELIVERY INFRASTRUCTUREPA OH TOTAL
Water Pipeline (Miles) 69 54 123
Connected Sources (MMGPD) 7.7 8.2 15.9
Cash Operating Margin: $517,000(1) $963,000(2)
Water Pipeline Water Pipeline to be ConstructedRICE Acreage
WetzelPA
OH
Greene
Washington
Monroe Marshall
Harrison
Jefferson
Ohio
Brooke
Beaver AlleghenyCarroll
Belmont
Monongahela River
Withdrawal
Ohio RiverWithdrawal
OH PA
WVGPOR Water Dedication
6 www.riceenergy.com
FINANCIAL SUMMARY
RMP Third Quarter 2015 Financial Summary
Third quarter average daily throughput of 671 MDth/d 3% increase from 2Q average throughput
Adjusted EBITDA of $15.6MM Distributable Cash Flow of $13.9MM DCF coverage ratio of 1.25x
Solid third quarter results supported by strong throughput growth, well capitalized balance sheet and ample liquidity
$100MM drawn under our revolving credit facility $19MM of cash on hand
Three Months Ended($ in millions, except per unit data) September 30, 2015Affiliate gathering volumes (MDth/d) 559 Third-party gathering volumes (MDth/d) 112
Total gathering volumes (MDth/d) 671
Total operating revenues $20.1
Total operating expenses $7.2Total operating income $13.0
Adjusted EBITDA $15.6
Distributable cash flow $13.9DCF / unit $0.2419
Distribution declared $11.1Distribution / unit $0.1935
DCF coverage ratio 1.25x
($ in millions) September 30, 2015Revolver capacity $450Less: Borrowings 100 Plus: Cash and cash equivalents 19
Liquidity $369
Increased distribution to $0.1935 / unit for 3Q15 $0.003 / unit increase
Expect to increase distributions with targeted 4Q15 distribution of $0.1965 / unit 5% increase above MQD of $0.1875 / unit
20% distribution growth target in 2016
__________________________1. Pro forma for close of water services business acquisition (excluding earn out) and private placement of common units for $175MM gross proceeds.
DISTRIBUTIONS
OPERATING METRICS LIQUIDITY AS OF SEPTEMBER 30, 2015(1)
Financial Summary
Three Months Ended
($ in millions, except per unit data)September 30, 2015
Affiliate gathering volumes (MDth/d)559
Third-party gathering volumes (MDth/d)112
Total gathering volumes (MDth/d)671
Total operating revenues$20.1
Total operating expenses$7.2
Total operating income$13.0
Adjusted EBITDA$15.6
Distributable cash flow$13.9
DCF / unit$0.2419
Distribution declared$11.1
Distribution / unit$0.1935
DCF coverage ratio1.25x
($ in millions)
Revolver capacity$ 450
Less: Borrowings30
Plus: Cash and cash equivalents—
Liquidity$ 420
EBITDA
Three Months Ended
($ in thousands)March 31, 2015
Adjusted EBITDA reconciliation to loss from continuing operations:
Net income$ 9,068
Interest expense394
Depreciation expense1,449
Amortization of intangible assets408
Non-cash stock compensation expense996
Amortization of deferred financing costs144
Adjusted EBITDA$ 12,459
Cash interest expense(394)
Estimated maintenance capital expenditures(1,120)
Distributable cash flow$ 10,945
Reconciliation of Adjusted EBITDA to Cash used in operating activities:
Adjusted EBITDA$ 12,459
Interest expense$ (394)
Changes in operating assets and liabilities which provided cash(12,134)
Net cash used in operating activities$ (69)
Financial Summary
Three Months Ended
($ in millions, except per unit data)March 31, 2015
Affiliate gathering volumes (MDth/d)557
Third-party gathering volumes (MDth/d)98
Total gathering volumes (MDth/d)655
Total operating revenues$ 20
Operating expenses67
Total operating income$ 13
Adjusted EBITDA$ 17
Distributable cash flow$ 15
DCF / unit$ 0.2624
Distribution declared$ 11
Distribution / unit$ 0.1905
Coverage ratio1.38x
Three Months Ended
($ in millions)September 30, 2015
Revolver capacity$450
Less: Borrowings100
Plus: Cash and cash equivalents19
Liquidity$369
EBITDA
Three Months Ended
($ in thousands)March 31, 2015
Adjusted EBITDA reconciliation to loss from continuing operations:
Net income$ 9,068
Interest expense394
Depreciation expense1,449
Amortization of intangible assets408
Non-cash stock compensation expense996
Amortization of deferred financing costs144
Adjusted EBITDA$ 12,459
Cash interest expense(394)
Estimated maintenance capital expenditures(1,120)
Distributable cash flow$ 10,945
Reconciliation of Adjusted EBITDA to Cash used in operating activities:
Adjusted EBITDA$ 12,459
Interest expense$ (394)
Changes in operating assets and liabilities which provided cash(12,134)
Net cash used in operating activities$ (69)
7 www.riceenergy.com
RMP Financial Overview
2015 UPDATED GUIDANCE(2)$ in millions, except per share data, as of 9/30/15Common Units 42 Subordinated Units 29
Total Units Outstanding (MM) 71 Price as of 9/30/15 $13.32
Market Capitalization $945Cash 19 Revolving credit facility 100
Enterprise Value $1,026
Leverage Statistics3Q15 Debt / EBITDA 1.2xEBITDA / Interest NMDebt to EBITDA Covenant 4.75x
Liquidity SummaryRevolving credit facility $450Less: amount drawn 100 Availability under RCF $350Plus: cash on hand 19 Liquidity as of 9/30/15 $369
2015 Capital Budget (in millions)
Gas Gathering $100Compression 90 Water 5
Total Expansion Capex $195Maintenance Capex 5
Total Capital Expenditures $200
GuidanceAdjusted EBITDA (in millions) $60 $65
% Third Party EBITDA 20%Distributable Cash Flow (in millions) $52 $57Average DCF Coverage Ratio 1.15x 1.2x2015 Distribution(3) ($ per unit) $0.7680
__________________________1. Pro forma for close of water services business acquisition (excluding earn out) and private placement of common units.2. As of November 5, 2015, unless otherwise stated.3. As of August 6, 2015.
CAPITALIZATION AND LIQUIDITY AT 9/30/15(1)
Sheet1
$ in millions, except per share data, as of 9/30/152015 Capital Budget (in millions)
Common Units42
Subordinated Units29Gas Gathering$ 85
Total Units Outstanding (MM)71Compression$ 90
Price as of 9/30/15$13.32Total Expansion Capex$ 175
Market Capitalization$945Maintenance Capex$ 5
Cash19Total Capital Expenditures$ 180
Revolving credit facility100
Enterprise Value$1,026
Guidance
Adjusted EBITDA (in millions)$55 $60
% Third Party20%
Leverage StatisticsDistributable Cash Flow (in millions)$48 $53
3Q15 Debt / EBITDA1.2xAverage DCF Coverage Ratio1.1x 1.2x
EBITDA / InterestNMAnnualized Distribution ($ per unit)$0.75
Debt to EBITDA Covenant4.75x
Liquidity SummaryRMP Units Owned
Revolving credit facility$450% of RMP Units - Public50%
Less: amount drawn100% of RMP Units - RICE50%
Availability under RCF$350% of RMP IDRs - RICE100%
Plus: cash on hand19
Liquidity as of 9/30/15$369
Sheet1
$ in millions, except per share data, as of 6/30/152015 Capital Budget (in millions)
Common Units29
Subordinated Units29Gas Gathering$100
Total Units Outstanding58Compression90
Water5
Price as of 6/30/15$ 17.36Total Expansion Capex$195
Market Capitalization$ 1,007Maintenance Capex5
Cash-Total Capital Expenditures$200
Revolving credit facility30
Debt-
Enterprise Value$ 1,037
Guidance
Adjusted EBITDA (in millions)$60 $65
% Third Party EBITDA20%
Leverage StatisticsDistributable Cash Flow (in millions)$52 $57
Debt / EBITDA[0.0x]Average DCF Coverage Ratio1.15x 1.2x
EBITDA / Interestnm2015 Distribution(3) ($ per unit)$0.7680
Debt to EBITDA Covenant4.75
Liquidity SummaryRMP Units Owned
Revolving credit facility$ 450% of RMP Units - Public50%
Less: amount drawn30% of RMP Units - RICE50%
Availability under RCF$ 420% of RMP IDRs - RICE100%
Plus: cash on hand-
Liquidity as of 3/31/15$ 420
8 www.riceenergy.com
Industry-Leading Throughput Growth3Q 2015 throughput of ~990 MDth/d through RICE and RMP midstream systems (23% 3rd Party), 12% increase from 2Q15 throughput
• RMP System: 671 MDth/d (17% 3rd Party)• RICE OH System: 319 MDth/d (36% 3rd Party)
RMP and RICE OH Midstream Historical Throughput
0
200,000
400,000
600,000
800,000
1,000,000
Dth/d
RMP - Rice Operated (PA) RMP - 3rd Party (PA) RICE - Rice Operated (OH) RICE - 3rd Party (OH)
Average Throughput (MDth/d)
2010 2011 2012 2013 2014 1Q 2015 2Q 2015 3Q 2015Throughput 4 18 61 176 409 668 887 990QoQ / YoY Growth 350% 238% 188% 133% 13% 33% 12%
(1)
__________________________1. PA 3rd party volumes as of April 2014 close of Momentum asset acquisition.
9 www.riceenergy.com
Attractive Drop Down Potential – OH GatheringSYSTEM MAPOVERVIEW
Includes OH gas gathering and compression assets OH gathering 3Q15 throughput of 319 MDth/d
̶ 36% 3rd party Gathering throughput driven by SE OH technical
leaders̶ ~65% of 2015E throughput from RICE
operated volumes, ~35% from GPOR(1)
Build-out is currently ahead of schedule̶ OH trunk line completed as designed in 2Q15
with 2.6 MMDth/d of capacity Will access TETCO, REX, DEO, and ET Rover to
deliver gas to Gulf Coast and Midwest markets 2015E EBITDA of $35MM - $40MM
Gathering System Information12/31/14
Dedicated Gross Acreage
3Q 2015 Throughput
(MDth/d)2015E Capex
($MM)(1)
RICE Retained Midstream 57,000
(2) 319 $300
Belmont
Marshall
JeffersonHarrison
Monroe
OHIO WEST VIRGINIA
LegendRICE Ohio Gathering Pipeline RICE Ohio Gathering Pipeline to be Constructed
GPOR Dedicated to RICERICE Acreage Dedicated to 3rd Party
GPOR Midstream JV(3)
Proposed Gathering for GPOR in Joint Venture
OH PA
WV
Guernsey
Premier Midstream Systems in Prolific Dry Gas Core Adds to Inventory of Drop Down Candidates__________________________1. As of November 5, 2015.2. 37,400 net acres from RICE and 19,600 net acres from GPOR.3. Under letter of intent (LOI).
10 www.riceenergy.com
Attractive Drop Down Potential – Strategic GPOR JV TRANSACTION OVERVIEW STRATEGIC RATIONALE
RICE and GPOR executed a non-binding LOI to form midstream JV to provide gas gathering, compression and water services to GPOR’s Eastern Belmont and Monroe acreage in Ohio
̶ JV will be supported by long-term, fee-based service agreements with GPOR
Ownership: RICE 75% and GPOR 25% with RICE to construct and operate all JV assets:̶ Dry gas gathering system with capacity to gather 1.8MMDth/d ̶ System will consist of ~165 miles of high and low pressure
12” – 30” gathering pipelines with multiple interconnections to Rockies Express, ET Rover, TETCO, Dominion East Ohio and other future pipelines
̶ ~50,000 horsepower of compression for gathering and delivery into various downstream interstate pipelines
̶ Fresh water distribution system designed to deliver fresh water to pads for well completion operations
GPOR will dedicate ~77,000 leasehold acres and contribute an existing 11-mile gas gathering pipeline and a 350 MDth/d TETCO interconnect in Monroe County
RICE and GPOR plan to invest ~$520MM to develop gathering and compression assets and ~$120MM for water assets
Constructing Extensive Dry Gas Gathering and Water Systems in One of the Most Prolific Natural Gas Plays
JV strengthens Rice’s leading midstream position in the core of the Utica Shale
̶ Expands relationship with GPOR across its premier position in the dry gas Utica Shale
Achieves efficiencies of simultaneous development of gathering and compression and water services businesses
Leverages existing footprint to grow 3rd party business and pursue additional 3rd party opportunities within a 340,000-acre AMI̶ System designed to accommodate future growth
Significantly adds to RICE’s attractive inventory of drop down candidates
11 www.riceenergy.com
RICE Overview
12 www.riceenergy.com
Concentrated, Core AssetsCORE ASSETS
Monroe
Harrison
Greene
WashingtonBelmont
Fayette
Monongalia
Utica Core
Marcellus Core
COMPANY TOTAL
UTICA
PA MARCELLUS
Highly concentrated position of ~147,000 net acres in the cores of the lowest breakeven gas shale plays in the U.S. ~1,230 net undeveloped locations(1)
609 MMcfe/d net 3Q15 production from 136 net wells Breakeven NYMEX PV-10 of $2.35-$3.05 / MMBtu 489 BBtu/d hedged in 2016 at $3.51 / MMBtu
~56,000 net Ohio Utica acres,
13 www.riceenergy.com
Increasing premium market exposure and narrowing differentials 76% of 3Q15 production transported outside of Appalachia
– Increases to 87% during 4Q15 Began utilizing 312 MDth/d of new FT on REX, UTGC & OPEN projects
Initiated production from 14 Marcellus wells; 8 wells ahead of schedule– Average lateral length of 6,940 ft. & avg. cost of $1,029 per lateral foot
1st PA Utica well turned to sales currently producing 12 MMcfe/d with favorable pressure declines
3Q15 net production of 609 MMcfe/d, 15% increase from 2Q15
~$1.2B pro forma liquidity (excl. RMP) to fund future development(1) Disciplined hedging strategy supports cash flow & protects balance sheet
– ~66% 3Q15 production hedged and $0.86/Mcf hedging price uplift Robust 2016 hedging portfolio of 489 BBtu/d at weighted avg. Henry Hub
floor price of $3.51/MMbtu
990 MDth/d total throughput with 23% third-party volumes in 3Q15 Executed midstream JV LOI w/ GPOR to construct & operate gathering,
compression & water services for their Utica acreage Successful drop down of PA & OH water assets to RMP for $200MM
purchase price
EXECUTION IS DRIVINGINDUSTRY–LEADING GROWTH
WELL-PROTECTED GROWTH &FINANCIAL FLEXIBILITY
DIVERSE FT PORTFOLIOENHANCES REALIZED PRICING
CREATING VALUE THROUGHMIDSTREAM DEVELOPMENT
RICE Third Quarter 2015 Highlights
__________________________1. Pro forma for October $750MM borrowing base re-determination and water services business acquisition, excluding earn out.
14 www.riceenergy.com
3Q15 net production of 609 MMcfe/d; 15% increase from 2Q15 Includes 30 MMcfe/d of positive working interest adjustments
76% of 3Q15 production sold to premium, non-Appalachian mkts Record adjusted EBITDAX of $119MM; 122% increase from 3Q14 Increased borrowing base ~15% to $750MM in October
RICE Third Quarter 2015 Financial Summary
FINANCIAL SUMMARYSolid third quarter results supported by well-capitalized balance sheet and ample liquidity
FINANCIAL & OPERATING STATISTICS9/30/2015
Total production (MMcfe/d) 609 % Gas 100%% Operated 92%% Marcellus 68%
Actual ($MM) $ / McfeNYMEX Henry Hub price ($/MMBtu) $2.73
Average basis impact ($/MMBtu) (0.38) Firm transportation fuel & variables ($/MMBtu) (0.14) Btu uplift (MMBtu/Mcf) 0.11
Pre-hedge realized price ($/Mcf) 2.32 Realized hedging gain ($/Mcf) 0.86
Post-hedge realized price ($/Mcf) 3.18 Net firm transportation sales -
Adjusted realized price ($/Mcf) $3.18
Lease operating $12 0.22 Gathering, compression and transportation 24 0.43 Production taxes and impact fees 2 0.03 General and administrative 24 0.43 Depletion, depreciation and amortization 89 1.59
Adjusted EBITDAX $119
($ in millions) 9/30/2015
CashRice Energy $221Rice Midstream Holdings 19 Rice Midstream Partners 19
Total consolidated cash $259
Long-term debtRice Energy
E&P credit facility - 6.25% Senior notes due 2022 900 7.25% Senior notes due 2023 397
Total Rice Energy debt 1,297 Rice Midstream Holdings revolver - Rice Midstream Partners revolver 100
Total consolidated debt $1,397Net debt 1,138
Shareholders equity $1,954Total capitalization $3,351
CAPITALIZATION AT 9/30/2015(1)
__________________________1. Pro forma for close of water services business acquisition (excluding earn out) and private placement of common units for $175MM gross proceeds.
Sheet1
2Q 2015
9/30/15($ in millions)3/31/15
Total production (MMcfe/d)609
% Gas100%Cash
% Operated92%Rice Energy $ 339
% Marcellus68%Rice Midstream Holdings 1
Actual ($MM)$ / McfeRice Midstream Partners 9
NYMEX Henry Hub price ($/MMBtu)$2.73Total consolidated cash $ 349
Average basis impact ($/MMBtu)(0.38)
Firm transportation fuel & variables ($/MMBtu)(0.14)Long-term debt
Btu uplift (MMBtu/Mcf)0.11Rice Energy
Pre-hedge realized price ($/Mcf)2.32E&P credit facility$ -52856580.22
Realized hedging gain ($/Mcf)0.866.25% Senior notes due 2022900Total production528.5658021978
Post-hedge realized price ($/Mcf)3.187.25% Senior notes due 2023397E&P Revenue101328730
Net firm transportation sales- 0Total Rice Energy debt1,2971.917050433
Adjusted realized price ($/Mcf)$3.18Rice Midstream Holdings revolver17Hedging Gain47042356.3958
Rice Midstream Partners revolver-Lease Operating12157013.4506
Lease operating$120.22Shareholders equity$ 1,996
Gathering, compression and transportation240.43Total capitalizationERROR:#REF!
Production taxes and impact fees20.03Total net capitalizationERROR:#REF!
General and administrative240.43
Depletion, depreciation and amortization891.59
Adjusted EBITDAX$119
Sheet1
2Q 2015
Actual($ in millions)9/30/15
Total production (MMcfe/d)529
% Gas99%Cash
% Operated90%Rice Energy $221
% Marcellus77%Rice Midstream Holdings 19
Rice Midstream Partners 19
NYMEX Henry Hub price ($/MMBtu)$ 2.72Total consolidated cash $259
Average basis impact ($/MMBtu)[(0.73)]
Firm transportation fuel & variables ($/MMBtu)[(0.01)]Long-term debt
Btu uplift (MMBtu/Mcf)0.10Rice Energy
Pre-hedge realized price ($/Mcf)2.08E&P credit facility-52856580.22
Realized hedging gain ($/Mcf)0.896.25% Senior notes due 2022900Total production528.5658021978
Post-hedge realized price ($/Mcf)2.977.25% Senior notes due 2023397E&P Revenue101328730
Net firm transportation sales0.01Total Rice Energy debt1,2971.917050433
Adjusted realized price ($/Mcf)$ 2.98Rice Midstream Holdings revolver-Hedging Gain47042356.3958
Rice Midstream Partners revolver100Lease Operating12157013.4506
Average costs per Mcfe:Actual ($MM)$ / McfeTotal consolidated debt$1,397EBITDAX1.7903163543
E&P Revenue (including net FT sales)$ 101$ 1.92Net debt1,138
Hedging gain470.89
Lease operating120.23Shareholders equity$1,954
Gathering, compression and transportation170.35Total capitalization$3,351Assets4,033,720
Production taxes and impact fees40.08Total net capitalization3,092Liabilities2,088,373
General and administrative190.391,945,347
Depletion, depreciation and amortization731.52
Adjusted EBITDAX$ 95$ 1.79
15 www.riceenergy.com
$625
$300 $350
$221
$846
$369
–
$200
$400
$600
$800
$1,000
Rice Energy Rice Midstream Holdings Rice Midstream Partners
Cash
AvailableRevolver
Strong Balance Sheet with Stable and Predictable Cash FlowsRICE is capable of funding 100% of 2015 capital plan with liquidity on-hand Favorable credit metrics & covenants ensure flexibility
Debt/EBITDA Covenant NONE 4.25x 4.75x3Q15 Debt / EBITDA 2.6x(3) NM 1.2x
EBITDA/Interest Covenant 2.5x 2.5x 2.5xLTM EBITDA/Interest 4.6x NM NM
(E&P)
(1)
__________________________Note: Pro forma for close of water services business acquisition (excluding earn out) and private placement of common units. (1) E&P segment cash balance.(2) Assumes $750MM borrowing base less $125MM letters of credit balance at 9/30/15.(3) Third quarter net debt, divided by run rate EBITDA, which is third quarter EBITDA annualized.
$MM
Leverage Metrics as of 9/30/15
$1.2B aggregate liquidity (excl. CFFO) v. remaining 2015 capex of ~$225MM
$369MM liquidity (excl. CFFO) v. remaining 2015 capex of ~$65MM
CASH & REVOLVER CAPACITY – 9/30/15
(2)
(1)
$100MM Accordion
$319
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Net Wells Spud Guidance ProductionPennsylvania 41 Total Net Production (MMcfe/d) 515 525
Operated Utica(2) 20 % Natural gas 100 % Non-operated Utica 9 % Marcellus 75 %
Ohio(2) 29 % Operated 93 %Total Net Wells Spud 70
Net Wells Turned to Sales Revenue DeductPennsylvania 34 Firm transportation fuel & variables(3) (0.17)$ (0.16)$
Operated Utica(2) 10 Non-operated Utica 2 Unit Cost ($/Mcfe)
Ohio(2) 12 Lease operating expense (0.28)$ (0.25)$ Total Net Wells Turned to Sales 46 Gathering and compression(3) (0.44)$ (0.39)$
Firm transportation expense(3) (0.42)$ (0.38)$ Average Lateral Lengths of Net Wells IP (ft.) Production taxes and impact fees (0.05)$ (0.04)$ Marcellus 7,100 Total Cash Unit Costs (1.19)$ (1.06)$ Operated Utica(2) 9,200Non-operated Utica 6,800 Cash G&A ($MM) 75$ 70$
Capital Expenditures PricingE&P Heat Content (Btu/Scf)Marcellus 330$ PA - Marcellus 1050Utica - Operated(2) 200$ OH - Utica 1080Utica - Non-operated 80$
Total Drilling & Completion 610$ Leasehold 120$
Total E&P Capex 730$ Retained MidstreamOhio Midstream and Water Systems(4) 300$
Total Capital Expenditures 1,030$
Guidance
2015 Updated RICE Guidance
__________________________1. As of November 5, 2015, unless otherwise stated.2. Includes one Pennsylvania Utica test well.3. As of May 7, 2015. Unit cost adjustments reflect a reallocation of cost between Gathering and Compression and Firm Transportation expense.4. Excludes $60 million of midstream capital expenditures incurred by RMP prior to its initial public offering payable by RICE in 2015.
Updates as of November 5, 2015: Increased net wells spud and net turned to sales Increased Capital Expenditures Increased net production range Decreased lease operating expense Increased Cash G&A
E&P GUIDANCE(1)
17 www.riceenergy.com
Ohio Utica Well Results To Date
Wells Turned Avg. Lateral Flow Rates (MMcf/d) D&CPeriod To Sales Length 0-90 91-180 181-360 ($/Ft)2Q 2014 1 6,957 14.0 14.2 15.9 3,316$ 3Q 2014 2 8,879 14.5 15.9 16.3 2,027$ 4Q 2014 - NA NA NA NA NA1Q 2015 2 8,639 16.0 13.5 NA 1,901$ 2Q 2015 11 9,963 15.4 NA NA 1,608$ 3Q 2015 - NA NA NA NA NA
Total 16 9,474 15.3 14.6 16.2 1,804$
* Flow rates based on wells with available history
Strong Execution Drives Consistent Results
__________________________1. Assumes RICE + GPOR collectively have a 90% working interest in a given unit.2. Based on production data as of September 30, 2015.
Consistent, Low Risk, Repeatable Results
Concentrated core Utica assets in southeastern OH RICE 62% operated and 43% non-operated avg. WI
with GPOR(1) in strategic AMI
17 operated (12 net) and 36 non-operated (7 net) wells producing at 3Q15 Avg. 3Q15 net production of 199 MMcfe/d
First PA Utica well turned to sales on August 25th
Initial flowback pressure of 10,254 psi
Producing at a restricted rate of 12 MMcf/d with favorable pressure declines
Concentrated core Marcellus assets in southwestern PA 114 net Marcellus wells producing at 3Q15
Avg. 3Q15 net production 410 MMcfe/d
Deep inventory of low-risk, low-breakeven Marcellus 10% IRR at $1.96/Mcf realized price ($2.60 NYMEX)
Multiple outlets (TCO, TETCO, DOM) with FT to premium markets (Gulf Coast, Midwest, Canada)
PENNSYLVANIA OPERATIONAL HIGHLIGHTS OHIO OPERATIONAL HIGHLIGHTS
(2) (2)
Marcellus Well Results To Date
Wells Turned Avg. Lateral Flow Rates (MMcf/d) D&CPeriod To Sales Length 0-90 91-180 181-360 ($/Ft)2010-2011 6 3,279 5.7 6.0 4.4 2,342$ 2012 9 5,731 9.2 10.0 6.8 1,583$ 2013 22 6,320 11.2 10.6 7.6 1,437$ 2014 41 7,272 10.6 9.2 7.2 1,236$ 1Q 2015 8 6,225 7.6 7.3 NA 1,312$ 2Q 2015 14 8,185 10.9 NA NA 1,219$ 3Q 2015 14 6,940 NA NA NA 1,029$
Total 114 6,754 10.1 9.1 7.0 1,338$
* Flow rates based on wells with available history
18 www.riceenergy.com
36% 51%
38% 51% 46%
18%
16%
18%
11% 6%
22%
20%
14% 15%
8%
24% 13%
30% 23% 40%
(0.38)
(0.28)
(0.43)
(0.32)
(0.41)
(0.50)
(0.45)
(0.40)
(0.35)
(0.30)
(0.25)
(0.20)
(0.15)
(0.10)
(0.05)
-
–
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
3Q15 4Q15 2015 2016 2017Gulf Coast TCO Midwest/Dawn DTI / M2 / M3 Basis Differential
Basis Exposure and Realized Pricing
Expect Appalachian basis exposure (M2/M3/DTI) to decrease throughout the year as firm transportation projects come online: REX (August 2015), Union Town to Gas City (Sept. 2015) and TETCO Open (Sept. 2015)
($0.43)/MMBtu basis differential in 2015
Firm transportation covers ~100% of 2015 production volumes
BASIS EXPOSURE AND BASIS DIFFERENTIAL$/MMBtu
_______________________1. Strip as of 10/23/15.
3Q15 4Q15 2015 2016 2017NYMEX Henry Hub Strip ($/MMBtu) $ 2.73 $ 2.36 $ 2.67 $ 2.67 $ 2.94 Plus/Less: Average Basis Impact (0.38) (0.28) (0.43) (0.32) (0.41) Less: Firm Transportation Fuel & Variables (0.14) (0.17) (0.13) (0.15) (0.12) Plus: BTU Uplift (MMBtu/Mcf) $ 0.11 $ 0.12 $ 0.11 $ 0.15 $ 0.16
Pre-Hedge Realized Price ($/Mcf) $ 2.32 $ 2.03 $ 2.22 $ 2.35 $ 2.57 Plus: Realized Hedging Gain/Loss ($/Mcf) 0.86 1.33 0.95 0.63 0.13
Post Hedged Realized Price ($/Mcf) $ 3.18 $ 3.36 $ 3.17 $ 2.98 $ 2.70 Plus: Firm Transportation Sales, Net ($/Mcf) - - 0.02 - -
Adjusted Post-Hedge Realized Price ($/Mcf) $ 3.18 $ 3.36 $ 3.19 $ 2.98 $ 2.70 FT Demand Expense ($/Mcf) (0.36) (0.47) (0.37) (0.42) (0.38)
FT Expense (Fuel & Variables + Demand) ($/MMBtu) (0.50) (0.64) (0.50) (0.57) (0.50) FT Expense + Basis + BTU Uplift ($/MMBtu) (0.77) (0.80) (0.82) (0.74) (0.75)
(1)
Basis & Pricing
90919292365365
Basis Exposure
1Q152Q153Q154Q15201520162017Rem 2015
Gulf Coast27%35%36%51%38%51%42%43%
TCO23%17%18%16%18%11%7%17%
Midwest/Dawn1%9%22%20%14%15%10%21%
DTI / M2 / M349%39%24%13%30%23%41%18%
Total100%100%100%100%100%100%100%100%
TETCO-M210%11%3%1%6%8%
M32%
Dominion39%26%17%12%21%15%
Realized Price
1Q152Q153Q154Q15201520162017
NYMEX Henry Hub Strip ($/MMBtu)$ 2.87$ 2.72$ 2.73$ 2.36$ 2.67$ 2.67$ 2.94
Plus/Less: Average Basis Impact(0.47)(0.61)(0.38)(0.28)(0.43)(0.32)(0.41)
Less: Firm Transportation Fuel & Variables(0.09)(0.13)(0.14)(0.17)(0.13)(0.15)(0.12)
Plus: BTU Uplift (MMBtu/Mcf)$ 0.11$ 0.10$ 0.11$ 0.12$ 0.11$ 0.15$ 0.16
Pre-Hedge Realized Price ($/Mcf)$ 2.42$ 2.08$ 2.32$ 2.03$ 2.22$ 2.35$ 2.57b
Plus: Realized Hedging Gain/Loss ($/Mcf)0.700.890.861.330.950.630.13
Post Hedged Realized Price ($/Mcf)$ 3.12$ 2.97$ 3.18$ 3.36$ 3.17$ 2.98$ 2.70
Plus: Firm Transportation Sales, Net ($/Mcf)0.080.01- 0- 00.02- 0- 0
Adjusted Post-Hedge Realized Price ($/Mcf)$ 3.20$ 2.98$ 3.18$ 3.36$ 3.19$ 2.98$ 2.70
FT Demand Expense ($/Mcf)(0.33)(0.31)(0.36)(0.47)(0.37)(0.42)(0.38)
FT Expense (Fuel & Variables + Demand) ($/MMBtu)(0.40)(0.42)(0.50)(0.64)(0.50)(0.57)(0.50)
FT Expense + Basis + BTU Uplift ($/MMBtu)(0.76)(0.93)(0.77)- 0(0.80)(0.82)(0.74)(0.75)
Gulf Coast
3Q154Q152015201620170.360.509603941863748360.380.510.42TCO
3Q154Q152015201620170.184592002954558690.161737027510178650.180.117.0000000000000007E-2Midwest/Dawn
3Q154Q152015201620170.220.201082810264009840.140000000000000010.148241516261466890.1DTI / M2 / M3
3Q154Q152015201620170.240.127576220362063260.30.229831181264245730.41Basis Differential
3Q154Q1520152016-0.38-0.28000000000000003-0.43-0.32-0.41
Hedging
Financial Hedging Detail
All-In Fixed Price Derivatives2015Rem. 20152016201720182019
NYMEX Natural Gas Swaps
Volume Hedged (BBtu/d)1661943081155–
Wtd. Avg. Swap Price ($/MMbtu)$4.09$4.07$3.87$3.81$3.60–
NYMEX Natural Gas Swing Swaps
Volume Hedged (BBtu/d)6–––––
Wtd. Avg. Swap Price ($/MMbtu)$2.77–––––
NYMEX Natural Gas Collars
Volume Hedged (BBtu/d)1391585022022050
Wtd. Avg. Collar Price ($/MMbtu)$4.65$4.65$3.60$3.61$3.69$3.78
Wtd. Avg. Floor Price ($/MMbtu)$3.96$3.96$2.91$3.13$3.20$3.24
Total NYMEX Price Derivatives
NYMEX Volume Hedged (BBtu/d)31135335833522550
% of Modeled Production61%51%34%17%3%
Swap & Collar Floor ($/MMbtu)$4.01$4.02$3.74$3.36$3.21$3.24
Dominion Natural Gas Swaps
Volume Hedged (BBtu/d)717131–––
Wtd. Avg. Swap Price ($/MMbtu)$2.53$2.49$2.62–––
TCO Natural Gas Swaps90440
Volume Hedged (BBtu/d)2941––––91529
Wtd. Avg. Swap Price ($/MMbtu)$3.30$3.30––––92512
92500
Total Fixed Price Derivatives365495.5
Total Fixed Volume Hedged (BBtu/d)410465389335225501.05531.3
% of Modeled Production80%56%34%17%3%
Swap & Collar Floor ($/MMbtu)$3.70$3.72$3.65$3.36$3.21$3.2488%
Basis Contract Derivatives2015Rem. 20152016201720182019
TCO Basis Swaps
Volume Hedged (BBtu/d)47533417––
Wtd. Avg. Swap Price ($/MMbtu)($0.36)($0.32)($0.33)($0.34)––
DOM Basis Swaps
Volume Hedged (BBtu/d)141645507560
Wtd. Avg. Swap Price ($/MMbtu)($1.12)($1.12)($1.10)($0.98)($0.70)($0.61)
M2 Basis Swaps
Volume Hedged (BBtu/d)24204060––
Wtd. Avg. Swap Price ($/MMbtu)($0.94)($0.94)($1.08)($1.01)––
ELA Basis Swaps
Volume Hedged (BBtu/d)2330603030–
Wtd. Avg. Swap Price ($/MMbtu)($0.13)($0.13)($0.10)($0.08)($0.09)–
MichCon Basis Swaps
Volume Hedged (BBtu/d)11244420
Wtd. Avg. Swap Price ($/MMbtu)($0.04)($0.04)($0.01)($0.04)($0.04)($0.12)
Chicago Basis Swaps
Volume Hedged (BBtu/d)––401010–
Wtd. Avg. Swap Price ($/MMbtu)––($0.05)($0.16)($0.19)–
ANR SE Basis Swaps
Volume Hedged (BBtu/d)––15–––
Wtd. Avg. Swap Price ($/MMbtu)––($0.13)–––
Physical Triggered Basis 2015Rem. 20152016201720182019
Appalachian Fixed Basis (Physical)
Volume Hedged (BBtu/d)252521–––
Wtd. Avg. Swap Price ($/MMbtu)($0.72)($0.72)($0.79)–––
MichCon Fixed Basis (Physical)
Volume Hedged (BBtu/d)2310108–
Wtd. Avg. Swap Price ($/MMbtu)$0.05$0.05$0.05$0.05$0.05–
Gulf Coast Fixed Basis (Physical)
Volume Hedged (BBtu/d)738710010010092
Wtd. Avg. Swap Price ($/MMbtu)($0.17)($0.17)($0.16)($0.16)($0.16)($0.16)
Total Basis Hedges
App1091141401277560
Gulf Coast9611717513013092
MichCon2574242220
Total Basis207235389281227172
Hedge & Basis Summary
Rem.
201520152016201720182019
Hedged M2 / Dominion Volumes (BBtu/d)1331321371107560
Wtd Avg Floor Price ($/MMBtu)$2.80$2.78$2.69$2.37$2.51$2.63
Weighted Strip as of 04/23/151.571.571.952.242.592.73
% of Estimated Production18%18%23%36%36%44%
% of Basis Hedged152%100%n.a.n.a.n.a.ERROR:#DIV/0!
% Unheded(52%)(26%)n.a.n.a.n.a.n.a.
Implied All-In Realized ($/MMBTU)$3.44$3.10n.a.n.a.n.a.n.a.
Hedged TCO Volumes (BBtu/d)76943417––
Wtd Avg Floor Price ($/MMBtu)$3.51$3.53$3.40$3.02––
Weighted Strip as of 04/23/152.742.742.862.912.943.02
% of Estimated Production14%17%11%7%5%4%
% of Basis Hedged114%100%n.a.n.a.n.a.–
% Unheded(14%)(19%)n.a.n.a.n.a.n.a.
Implied All-In Realized ($/MMBTU)$3.62$3.67n.a.n.a.n.a.n.a.
Hedged Gulf Coast Volumes (BBtu/d)199234144183128–
Wtd Avg Floor Price ($/MMBtu)$3.93$3.94$3.57$3.26$3.06–
Weighted Strip as of 04/23/152.842.843.103.233.303.38
% of Estimated Production50%43%51%47%49%43%
% Hedged at Henry Hub83%82%39%40%19%–
% of Basis Hedged40%50%n.a.n.a.n.a.14%
% Unheded17%18%n.a.n.a.n.a.n.a.
Implied All-In Realized ($/MMBTU)$3.75$3.74n.a.n.a.n.a.n.a.
Hedged Chicago/Dawn Volumes (BBtu/d)2574242220
Wtd Avg Floor Price ($/MMBtu)$4.03$4.04$3.71$3.31$3.13$3.12
Weighted Strip as of 04/23/153.013.013.073.063.093.19
% of Estimated Production18%21%15%10%10%9%
% of Basis Hedged3%4%n.a.n.a.n.a.14%
Total Hedged Volumes (BBtu/d)41046538933522580
Wtd Avg Fixed Floor Price ($/MMBtu)$3.72$3.65$3.36$3.21
Wtd Avg Basis Floor Price ($/MMBtu)$3.49$3.53$3.27$2.96$2.88$2.76
% Hedged88%n.a.n.a.n.a.n.a.
% Hedged76%80%56%34%17%5%
9/30 Min % Hedged75%75%63%46%40%
Contracts to Execute113283957
Net Production (BBtu/d)531
Bryan Stephenson: Bryan Stephenson:Updated Guidance6979811,3411,553
100%100%100%100%
2Q15 Hedging
2Q15 Hedged Production
4/30/155/31/156/30/15
Swap Volume (BBtu)3,8204,7904,610
Swing Swaps (BBtu)–1,230840
Collar Volume (BBtu)3,6003,4103,600
Deferred Put Volume (BBtu)–––
Double Ups–––
Extendibles–––
Total Hedged Volume (BBTU)7,4209,4309,050
Hedged Volume Less Deferred Puts (BBtu)7,4209,4309,050
Hedged Volumes
Total NYMEX (BBTU)7,4209,4309,050
DOMSP2,6551,8762,025
TCO1,245977645
Total Hedged Volume (BBTU)11,32012,28211,720
Wtd. Average Floor
Total NYMEX (BBTU)$4.04$3.87$3.91
DOMSP$2.51$2.50$2.55
TCO$3.30$3.29$3.31
2Q15 Wtd. Average Floor$3.62
2Q15 % Fixed Price Hedged70%
Total 2Q15 ProductionMMcfe/d529
MMcfe9148,139
BBtu1.0550,546
Hedged VolumesBBtu35,322
19 www.riceenergy.com
$ millions, except per unit data, as of 11/4/15
Common Units 42 Subordinated Units 29
Total Units Outstanding (MM) 71 Price as of 11/4/2015 $14.00
Market Capitalization $994Cash (1) 19 Revoling credit facility (1) 100
Enterprise Value $1,075
Distribution / Unit $0.1935Yield 5.53%
52 Week Price RangeHigh $17.94Low $11.22
Website:Investor Contact:
www.ricemidstream.com
[email protected] Danvers
RMP and RICE Market SnapshotRice Midstream Partners LP
(NYSE: RMP)Rice Energy Inc.
(NYSE: RICE)
__________________________1. As of September 30, 2015, pro forma for close of water services business acquisition and private placement of common units.
(1)
$ millions, except per share data, as of 11/4/15
Management Ownership 30%
Shares Outstanding (MM) 136Price as of 11/4/2015 $16.14
Market Capitalization $2,200Cash (1) 240 Revoling credit facilities (1) –6.25% Senior notes due 2022 9007.25% Senior notes due 2023 397
Enterprise Value $3,257
52 Week Price RangeHigh $29.18Low $14.90
Website: www.riceenergy.comInvestor Contact: Julie Danvers
20 www.riceenergy.com
Appendix
21 www.riceenergy.com
0
20
40
60
80
100
120
140
160
180
200
2007 2008 2009 2010 2011 2012 2013 2014 2015 2016
Industry Activity – Concentrated in the Core
99
755
44
333
312
29
429
42
6
0 5 10 15 20 25 30 35
Peer 1
Peer 2
Peer 3
Rice Energy
Peer 5
Peer 6
Peer 7
Peer 8
Peer 9
Peer 10
Top Ten Active Operators
Laid Down From PeakActive
October 2015: 66 Rigs
Rig Count
PA Marcellus
Pennsylvania
West Virginia
Ohio
RMP Core Position + Quality Customers = Downside Protection in Current Environment
Oct 201566 Rigs
Oct 200966 Rigs
Appalachia Rig Counts(1): 2007 - 2015
10+ Rigs
5-9 Rigs
3-4 Rigs
1-2 Rigs
RICE Acreage
# of R
igs
__________________________(1) RigData + Baker Hughes Rig Reports.
Early 2012 Peak of 175 Rigs
Activity migrated to most economic counties
RMP’s assets are located in three of the four most active counties in Appalachia
RMP Primary Customers
22 www.riceenergy.com
RICE and RMP Organizational Structure
DE
PA Water
OH Gathering IDRs & LP
Interests
41%LP interest59% LP interest
Non-economic GP Interest
RICE owns 100% of the GP and IDRs and a 41% LP ownership, creating alignment between RMP and RICE
Drop Down Assets
$300MM Credit Facility +
$450MM Credit Facility
Rice Midstream Holdings LLC
Rice Midstream Management LLC(General Partner)
Public Unitholders
Gulfport JV(1)
ROFOAssets
$750MM Credit Facility
$100MM Accordion Feature
OH WaterPA Gathering
__________________________(1) Under letter of intent (LOI).
23 www.riceenergy.com
Efficient Capital Allocation Drives Strong 2015 Growth
_______________________Note: 2014 Pro Forma for ASR transaction.1. As of November 5, 2015.2. Does not include wells from the Greene County Acquisition.3. Consolidated midstream includes Rice Midstream Holdings and Rice Midstream Partners.
47
127
274
520
–
–
0
100
200
300
400
500
2012 2013 2014 2015E
MMcfe/d
Average Net Daily ProductionNet Wells Turned to Sales(2)
Midstream Capital Expenditures Daily Throughput 2015E Midstream EBITDA
$45 $150 $200
$150
$300
$45 $50
$300
$500
0
100
200
300
400
500
2012 2013 2014 2015E
$MM
RMP Rice Retained Midstream
61
625
245
175
401
870
0
150
300
450
600
750
900
2012 2013 2014 2015E
MDth/d
RMP Rice Retained Midstream
$63
$38
0
10
20
30
40
50
60
RMP Rice RetainedMidstream
$MM
Published Guidance
D&C & Land Capital Expenditures
$380 $330
$200 $280
$250 $120
$225
$545
$830 $730
0100200300400500600700800900
2012 2013 2014 2015E
$MM
PA D&C OH D&C Land
2015E UPDATED E&P GUIDANCE(1)
2015E UPDATED CONSOLIDATED MIDSTREAM GUIDANCE(1)(3)
36 34 –
–
7 12
10
21
43 46
0
10
20
30
40
50
2012 2013 2014 2015E
Wells
PA OH
24 www.riceenergy.com
3Q 2015 Adjusted EBITDA and DCF Reconciliation
__________________________Note: Adjusted EBITDA is a supplemental non-GAAP financial measure that is used by management and external users of our consolidated financial statements, such as industry analysts, investors, lenders and rating agencies. We define Adjusted EBITDA as net income (loss) attributable to us before non-controlling interest, interest expense or interest income; income taxes; write-down of abandoned leases; depreciation, depletion and amortization; amortization of deferred financing costs; amortization of intangible assets; equity in (income) loss of our joint ventures; derivative fair value (gain) loss, excluding net cash receipts on settled derivative instruments; non-cash stock compensation expense; (gain) loss from sale of interest in gas properties; (gain) loss on acquisition; acquisition expense; (gain) loss on extinguishment of debt; write-off of deferred financing costs; and exploration expenses. Adjusted EBITDA is not a measure of net income as determined by United States generally accepted accounting principles, or GAAP.
Three Months Ended Nine Months Ended($ in thousands) September 30, 2015 September 30, 2015Adjusted EBITDA reconciliation to loss from continuing operations:Net income 12,270$ 33,670$
Interest expense 557 1,408Depreciation expense 1,597 4,531Amortization of intangible assets 407 1,223Non-cash stock compensation expense 961 2,960Amortization of deferred financing costs 144 432Other expense (347) 492
Adjusted EBITDA 15,589$ 44,716$ Cash interest expense (557) (1,408) Estimated maintenance capital expenditures (1,120) (3,360)
Distributable cash flow 13,912$ 39,948$
Reconciliation of Adjusted EBITDA to Cash used in operating activities:Adjusted EBITDA 15,589$ 44,716$
Interest expense (557) (1,408) Other expense 347 (492) Changes in operating assets and liabilities which provided cash 17,092 (8,176)
Net cash provided by operating activities 32,471$ 34,640$
Financial Summary
Three Months Ended
($ in millions, except per unit data)September 30, 2015
Affiliate gathering volumes (MDth/d)559
Third-party gathering volumes (MDth/d)112
Total gathering volumes (MDth/d)671
Total operating revenues$20.1
Operating expenses$7.2
Total operating income$12.9
Adjusted EBITDA$15.5
Distributable cash flow$13.8
DCF / unit$0.2406
Distribution declared$11.0
Distribution / unit$0.1935
Coverage ratio1.26x
Three Months Ended
($ in millions)September 30, 2015
Revolver capacity$ 450
Less: Borrowings72
Plus: Cash and cash equivalents19
Liquidity$ 397
EBITDA
Three Months EndedNine Months Ended
($ in thousands)September 30, 2015September 30, 2015
Adjusted EBITDA reconciliation to loss from continuing operations:
Net income$ 12,270$ 33,670
Interest expense5571,408
Depreciation expense1,5974,531
Amortization of intangible assets4071,223
Non-cash stock compensation expense9612,960
Amortization of deferred financing costs144432
Other expense(347)492
Adjusted EBITDA$ 15,589$ 44,716
Cash interest expense(557)(1,408)
Estimated maintenance capital expenditures(1,120)(3,360)
Distributable cash flow$ 13,912$ 39,948
Reconciliation of Adjusted EBITDA to Cash used in operating activities:
Adjusted EBITDA$ 15,589$ 44,716
Interest expense(557)(1,408)
Other expense347(492)
Changes in operating assets and liabilities which provided cash17,092(8,176)
Net cash provided by operating activities$ 32,471$ 34,640
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DisclaimerFORWARD-LOOKING STATEMENTSThis presentation and the oral statements made in connection therewith may contain “forward looking statements” within the meaning of the securities laws. All statements, other than statements of historical fact, regarding Rice Midstream’s strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. These statements often include the words “could,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “project” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. Without limiting the generality of the foregoing, forward-looking statements contained in this presentation specifically include expectations of plans, strategies, objectives, anticipated financial and operating results of Rice Midstream and RICE and the closing of Rice Midstream’s private placement of common units. These forward-looking statements are based on Rice Midstream's current expectations and assumptions about future events and are based on currently available information as to the outcome and timing of future events. Rice Midstream assumes no obligation to and does not intend to update any forward looking statements included herein. When considering forward-looking statements, you should keep in mind the risk factors and other cautionary statements described under the heading “Risk Factors” included in Rice Midstream’s the most recent Form 10-K, Form 10-Q, and other filings with the Securities and Exchange Commission. These forward-looking statements are based on Rice Midstream’s current belief, based on currently available information, as to the outcome and timing of future events. Rice Midstream cautions you that these forward-looking statements are subject to all of the risks and uncertainties, most of which are difficult to predict and many of which are beyond their control, incident to the exploration for and development, production, gathering and sale of natural gas, natural gas liquids and oil. These risks include, but are not limited to, commodity price volatility, inflation, lack of availability of drilling and production equipment and services, environmental risks, drilling and other operating risks, regulatory changes, the uncertainty inherent in estimating natural gas reserves and in projecting future rates of production, cash flow and access to capital, the timing of development expenditures, and the other risks described under “Risk Factors” in Rice Midstream’s most recent Form 10-K, Form 10-Q and other filings with the Securities and Exchange Commission. Should one or more of these risks or uncertainties occur, or should underlying assumptions prove incorrect, Rice Midstream’s actual results and plans could differ materially from those expressed in any forward-looking statements.This presentation has been prepared by Rice Midstream and includes market data and other statistical information from sourcesbelieved by Rice Midstream to be reliable, including independent industry publications, government publications or other published independent sources. Some data are also based on Rice Midstream’s good faith estimates, which are derived from its review ofinternal sources as well as the independent sources described above. Although Rice Midstream believes these sources are reliable, it has not independently verified the information and cannot guarantee its accuracy and completeness.
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Determination of Identified Drilling Locations as of December 31, 2014
Net undeveloped locations are calculated by taking RICE’s total net acreage and multiplying such amount by a risking factor which is then divided by RICE’s expected well spacing. RICE then subtracts net producing wells to arrive at undeveloped net drilling locations
Undeveloped Net Marcellus Locations: RICE assume these locations have 7,000 foot laterals and 750 foot spacing between wells which yields approximately 121 acre spacing. In the Marcellus, we apply a 20% risking factor to its net acreage to account for inefficient unitization and the risk associated with its inability to force pool in Pennsylvania. As of 12/31/14, RICE had 64,355 net acres in the Marcellus which results in 356 undeveloped net locations
Undeveloped Net Western Greene County Locations: RICE assumes these locations have 7,000 foot laterals and 750 foot spacing between wells which yields approximately 121 acre spacing. In Western Greene County, RICE applies a 20% risking factor to its net acreage to account for inefficient unitization and the risk associated with its inability to force pool in Pennsylvania. As of 12/31/14, RICE had 22,000 net acres in Western Greene County which results in 139 undeveloped net locations
Undeveloped Net Upper Devonian Locations: RICE assumes these locations have 7,000 foot laterals and 1,000 foot spacing between wells which yields approximately 161 acre spacing. In the Upper Devonian, we apply a 20% risking factor to its net acreage to account for inefficient unitization and the risk associated with its inability to force pool in Pennsylvania. As of 12/31/14, RICE had 77,242 net acres prospective for the Upper Devonian which results in 382 undeveloped net locations
Undeveloped Net Utica Locations: RICE assumes these locations have 8,000 foot laterals and 750 foot spacing between wells which yields approximately 138 acre spacing. In the Utica, RICE applies a 10% risking factor to its net acreage to account for inefficient unitization. As of 12/31/14, RICE had 55,000 net acres prospective for the Utica in Ohio which results in 356 undeveloped net locations. This excludes ~2,500 net acres in Guernsey and Harrison Counties in Ohio
Additional Disclosures
�Rice Midstream Partners�Third Quarter 2015 Supplemental Slides� November 5, 2015RMP: High Growth MLP in Prolific Appalachian BasinRMP Third Quarter 2015 HighlightsSuccessful Water Services Business Acquisition SummaryAcquisition Assets – Integrated Water Services BusinessRMP Third Quarter 2015 Financial SummaryRMP Financial OverviewIndustry-Leading Throughput GrowthAttractive Drop Down Potential – OH GatheringAttractive Drop Down Potential – Strategic GPOR JV RICE OverviewConcentrated, Core AssetsRICE Third Quarter 2015 HighlightsRICE Third Quarter 2015 Financial Summary Strong Balance Sheet with Stable and Predictable Cash Flows2015 Updated RICE GuidanceStrong Execution Drives Consistent ResultsBasis Exposure and Realized PricingRMP and RICE Market SnapshotAppendixIndustry Activity – Concentrated in the CoreRICE and RMP Organizational StructureEfficient Capital Allocation Drives Strong 2015 Growth3Q 2015 Adjusted EBITDA and DCF ReconciliationDisclaimerAdditional Disclosures