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Investor Presentation · 04/05/2020 · At $2.50/MMBtu NYMEX and $25.00/Bbl WTI oil price, expect...
Transcript of Investor Presentation · 04/05/2020 · At $2.50/MMBtu NYMEX and $25.00/Bbl WTI oil price, expect...
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Investor Presentation
May 2020 UpdateMay 4, 2020
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National Fuel is committed to the safe and environmentally conscious development, transportation, storage, and
distribution of natural gas and oil resources.
For additional information, please visit our corporate responsibility website at https://responsibility.natfuel.com
https://responsibility.natfuel.com/
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A message from David Bauer, President and CEO of National Fuel Gas Company, on NFG’s COVID-19 response“As we confront the challenges of the COVID-19 pandemic, I am proud to say that National Fuel
has continued to safely and reliably provide natural gas service to our over 743,000 utility customers in western New York and northwestern Pennsylvania, operate our extensive network of transportation, compression and gathering infrastructure, and produce critical natural gas supplies.
The continuity of our operations is a direct result of the dedication and hard work of our over 2,000 employees. During this unprecedented situation, National Fuel has remained committed to our workforce -the bedrock of our Company - and has not instituted any furloughs or workforce reductions. With a large portion of our employees now working remotely, we have implemented a number of initiatives to provide the flexibility needed to address this new normal, including additional paid time off to address child care needs, and encouraging the use of alternative work schedules.
With respect to our in-field workforce and customer service representatives, all of whom provide essential services to our communities each and every day, we have adopted appropriate social distancing measures and have provided necessary personal protective equipment in line with directives from federal, state, and local agencies. As this public health crisis evolves, the health and well-being of our employees and our communities will remain our number one priority, and National Fuel will continue to monitor developments affecting our stakeholders in order to take appropriate steps to mitigate the impacts of the COVID-19 virus.”
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Acquisition of Shell’s Integrated Appalachian Upstream and Midstream Assets
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Strategic Rationale - Strengthens NFG’s Integrated Model
Acquisition Expected to Deliver Meaningful Free Cash Flow Generation, While Maintaining Contribution from Regulated Businesses, and Building on Integrated Model
Seneca to acquire contiguous assets, with shallow declining PDP reserves, at less than $0.40 per Mcf(1) PV20+ at current natural gas strip, including only estimated PDP reserves (no value attributed to undeveloped locations)
Expected to lower upstream unit costs through highly synergistic addition to existing Tioga County operations Improvements to both DD&A and G&A (each expected to improve ~$0.05/Mcfe in fiscal 2021)
Increases flexibility to allocate future development capital across different operating areas (Tioga, Lycoming, WDA) Near and medium-term capital expenditures expected to be unchanged post-acquisition
Considerable benefits for midstream businesses (~$35 MM in incremental gathering EBITDA in 12 months post-close) Seneca will acquire valuable Shell’s transportation contract on Empire (200 MDth/day), with access to premium markets
Seneca and Gathering expected to generate free cash flow at NYMEX price of $2.00 or higher in 12 months post-close At $2.50/MMBtu NYMEX and $25.00/Bbl WTI oil price, expect to generate over $100 million in free cash flow over same period(3)
(1) This presentation includes forward-looking statements. Please review the safe harbor for forward looking statements at the end of this presentation.(2) Average weighted NYMEX hedge price ($/MMBtu) for specified fiscal year.(3) Free Cash Flow is defined on page 73 of this presentation. Assumes current hedges.
Significant additional hedges executed for fiscal 2021 and 2022, protecting economics and free cash flow generation Hedges in place equivalent to ~75% of acquired 2021 PDP volumes ($2.71) and ~55% of acquired 2022 PDP volumes ($2.54)(2)
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Acquisition of Highly-Integrated Assets at Attractive Valuation
$500 million purchase of Royal Dutch Shell’s Appalachian assets(1)
215-230 MMcf/day of net production(2), with 70-75 Bcf of expected production in 12 months post-closing
710 Bcf of net proved developed producing reserves(2)
142 miles of gathering pipelines, compression, and related facilities
Over 400,000 net acres in Appalachia, with ~200,000 acres in Tioga County, contiguous to NFG’s existing footprint
300 MDth/d of transportation capacity, including 200 MDth/d on Empire (NFG)
Over $125 million in incremental EBITDA expected in twelve months post-closing, with ~$35 million from Gathering(3)
WDA – ~915,000 Acres(715,000 - NFG / ~200,000 - Shell)
EDA – ~270,000 Acres (70,000 - NFG / ~200,000 Shell)
(1) Approximate purchase price at time of closing, after estimated closing adjustments.(2) Production and reserves (P90) are estimated at time of closing.(3) Assumes current hedges, $2.50/MMBtu NYMEX natural gas price, and $25/Bbl WTI oil price.
EBITDA is defined on page 73 of this presentation.
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~185 additional drilling locations (~150 Utica and ~35 Marcellus) with 86-87% average NRI
Integrated gathering assets expected to move 255-270 MMcf/d of gross production(1)
Seneca to acquire valuable pipeline capacity, with acquired gathering highly interconnected
200 MDth/d on Empire Pipeline (NFG)
100 MDth/d on Dominion reaches Transco Leidy line, providing optionality for future Leidy South volumes (Transco/NFG)
Interconnections with additional interstate pipelines (TGP, UGI)
Potential to tie acquired gathering facilities into NFG’s existing Covington system
Significant Integrated Operations in Tioga County
Synergistic E&P and Gathering Assets, Contiguous to NFG’s Highly-Economic Tioga
County Development and Operations
(1) Estimated at time of closing.
Empire (NFG)
DCNR 007
DCNR 595
Covington
Undeveloped Utica
Undeveloped Marcellus
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Increased Production Base Drives Lower E&P Unit Costs
Immediate Unit Cost Reductions Expected from Additional Scale in Appalachia
Total Exploration & Production Cash OpEx ($/Mcfe)(1)
$0.56 $0.57
$0.32 $0.28
$0.30 $0.27
$0.14$0.11
$1.32~$1.23
FY 2019 FY 2020E FY 2021E(Post-Acqusition)
LOE (Affiliated Gathering) Other LOE G&A Taxes & Other
$0.05 to $0.08 / Mcfe of Cash Unit Costs
Reductions
(1) A non-GAAP reconciliation of E&P Operating Costs is included at the end of this presentation.
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Acquisition of Mature PDP Stream with Low Base Decline
Shallow Decline of Acquired Production Supports Long-Term Unit Cost Synergies
Annual Appalachian Production Base Decline (%)
0%
5%
10%
15%
20%
25%
30%
35%
40%
Shell Seneca Peer 1 Peer 2 Peer 3 Peer 4 Peer 5 Peer 6
Peer Average(1)
(1) Peers include AR, CNX, COG, EQT, RRC, and SWN. Source - RS Energy Group. Seneca and Shell base declines are per internal estimates. Estimated base declines for period commencing January 1, 2020.
Acquisition PDP Declines Shallower than Appalachia Peers, with Decline Rate Expected to be Below 20% at Closing
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Continued Commitment to Prudent Capital Allocation
E&P Capital Expenditure Guidance Further Reduced, With Near-Term Activity Levels Unchanged
E&P
$492
$415-$455 $375-
$410$375-$395
-2019 Actual 2020EGuidance (Aug. '19)
2020EGuidance (Feb. '20)
2020E 2021E(Post-Transaction)
Full Year at 3 rigs
Exploration & Production Capital Expenditures ($ Millions)(1)
Reduced Activity to
2 rigs Further Reduced Activity
Continued Lower
Activity Continued Lower
Activity (1 rig)
(1) A reconciliation to Capital Expenditures as presented on the Consolidated Statement of Cash Flows is included at the end of this presentation.
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Strong Hedge Position Solidifies Economics of Acquisition
(1) Based on PDP production estimate at time of closing. (2) Hedge percentage represents percentage of fixed price natural gas firm sales and NYMEX hedges at midpoint of production guidance range.(3) Average weighted floor and ceiling prices. (4) Fixed price physical sales exclude joint development partner’s share of fixed price contract WDA volumes as specified under the joint development agreement, and are net of transportation costs. Swaps and 2-way collar prices do not include cost of
transport.
2.4
25.9
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40.6
46.8
29.6
62.6
118.5
49.3
Swaps Fixed Price Physical 2-Way Collars(4)
Pro Forma Natural Gas Hedges - MMDth, $/MMBtu
105.5 MMDth
191.2MMDth
78.9MMDth
~62% Hedged(2)
$2.69
$2.18
$2.61
$2.22
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$2.28 / $2.77(3)
$2.52
$2.23
$2.28 / $2.77(3)
Fisc
al 2
020
Fisc
al 2
021
Fisc
al 2
022
Significant Additional Hedges Executed, Minimizing Commodity Price Risk
Seneca has entered into additional NYMEX natural gas swaps in fiscal 2021 and 2022, locking in strong returns, with volumes equivalent to:
2021: ~75% of acquisition PDP production(1)
2022: ~55% of acquisition PDP production
Overall hedge percentage also significantly increased, capitalizing on recent run-up in natural gas prices:
Hedges in place for ~75% of estimated 2021 PDPs
2021: ~130 Bcf of new hedges
2022: ~63 Bcf of new hedges
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Financing Supportive of Investment Grade Credit Rating . . .
Expected to be accretive to existing credit metrics and to maintain investment grade credit ratings
Post-closing, E&P and Gathering expect to generate combined free cash flow over next 12 months at NYMEX prices of $2.00/MMBtu or higher, supporting credit metrics and investment grade credit ratings(1)
Over $100 million in estimated E&P and Gathering free cash flow generation at NYMEX of $2.50/MMBtu, WTI oil of $25.00/Bbl, and assuming current hedges over same period
Transaction expected to be permanently financed with approximately equal proportions of equity, including equity-linked securities, and long-term debt
Equity backstop to seller significantly de-risks financing strategy, and supports investment grade credit rating
NFG has the right to issue up to $150 million of common equity at a pre-determined price to Shell at closing of the transaction, providing additional financing flexibility to NFG(2)
Existing liquidity affords NFG with flexibility to be opportunistic in accessing capital markets
Existing multi-year credit facility provides approximately $550 million of liquidity
Additional $200 million, 364-day unsecured revolving credit facility closed in April 2020
. . . With Appalachian Program Well-Positioned to Generate Sustainable Free Cash Flow
(1) The company defines free cash flow as funds from operations less capital expenditures.(2) Shares would be issued at price of $38.97 per share.
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Acquisition Provides Unique Long-Term Growth Opportunity
Attractive Valuation
Integrated Assets
Synergistic Operations
Valuable Pipeline Capacity
Increased Scale
CapEx Plans Unchanged
Enhances Free Cash Flow
Supports Credit Ratings
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Operations and Business Overview
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Developing our large, high quality acreage position in Marcellus & Utica shales(1)
NFG: A Diversified, Integrated Natural Gas Company
Providing safe, reliable and affordable service to customers in WNY and NW Pa.
UpstreamExploration &
Production
MidstreamGathering
Pipeline & Storage
38% of NFG EBITDA(1)
DownstreamUtility
% of NFG 20EBITDA(1)
Expanding and modernizing pipeline infrastructure to provide outlets for Appalachian natural gas production
~785,000Net acres in Appalachia
~610 MMcf/dayNet Appalachian natural gas production
$1.7 BillionInvestments
since 2010
3.9 MMDthDaily interstate pipeline capacity under contract
743,400Utility
customers
$324 MillionInvestments in safety since 2015
(1) Twelve months ending March 31, 2020. A reconciliation of Adjusted EBITDA to Net Income as presented on the Consolidated Statement of Income and Earnings Reinvested in the Business is included at the end of this presentation.
44% of NFG EBITDA(1)
36% of NFG EBITDA(1)
20% of NFG EBITDA(1)
Acquisition to add ~400,000 net acres, 215-230 MMcf/d of net production,
and ~142 Miles of gathering
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Why National Fuel?
Diversified Assets Provide Stability and Long-Term Growth Opportunities
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Midstream
Integrated Model Enhances Shareholder Value . . .
Ability to adjust to changing commodity price environments
More efficient capital investment Higher returns on investment Operational scale Lower cost of capital Lower operating costs More competitive pipeline
infrastructure projects Strong balance sheet Growing, stable dividend
Geographic and Operational Integration Drives Synergies:
Benefits of National Fuel’s Integrated Structure:
Financial Efficiencies: Investment grade credit rating Shared borrowing capacity Consolidated income tax return
DownstreamUtility
MidstreamGathering
Pipeline & Storage
UpstreamExploration &
Production
Co-Development of Marcellus and Utica Just-in-time gathering facilities Pipeline expansion opportunities
Upstream
Rate-regulated entities share common resources, reducing operating expense
Utility business is a large Pipeline & Storage customer
DownstreamMidstream
1
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Acquisition of significant, contiguous Tioga County acreage and supporting gathering facilities furthers NFG’s focus on integrated Upstream and Midstream development within Appalachia
Over 1.2 million acre position in the Marcellus and Utica shales (inclusive of acquisition acreage)
NFG’s gathering systems move Seneca’s natural gas production, driving consolidated returns
NFG’s interstate pipelines support Appalachian development and provide new firm takeaway capacity
Further expansion of interstate pipeline systems to satisfy growing natural gas supply and demand
Supply push – Appalachian producers
Demand pull – regional demand-driven projects and utilities
Ongoing investment in safety and modernization of pipeline transportation and distribution systems
$500+ million in new investments expected over the next 5 years
. . . and Continues to Drive Growth Opportunities
Near Term Strategy Leverages Integration Across the Value Chain
UtilityGathering Pipeline & Storage Exploration &
Production
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Impressive Dividend History
Annual Rate at Fiscal Year End
$3.1 BillionDividend payments since 1970
$1.74per share
49 YearsConsecutive Dividend Increases
$0.19per share
117 YearsConsecutive Payments
4.2%yield(1)
(1) As of April 30, 2020.
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Appalachian Program Expected to Generate Free Cash Flow . . .
(1) The Company defines free cash flow on page 73 of this presentation. Assumes current hedges and $25/Bbl WTI oil price in the 12 months post-closing of acquisition (August 1, 2020 – July 31, 2021).
3
. . . During the 12 months Post-Acquisition at Natural Gas Prices of $2.00/MMBtu or Higher . . .
. . . While Generating Strong Consolidated Returns Across Seneca’s Acreage Footprint
$2.25IRR (%) (2)
$2.00IRR (%) (2)
Tract 100 & GambleLycoming Co.
Marcellus 73% 59% $1.11
Tioga County Utica 57% 47% $1.34
CRV Return Trip Utica 30% 25% $1.60
CRV Return Trip Marcellus 33% 26% $1.57WDA
Prospect ReservoirRealized Pricing (2) 15% IRR (3)
RealizedPrice
EDA
(2) Net realized price reflects either (a) price received at the gathering system interconnect or (b) price received at delivery market net of firm transportation charges.(3) Consolidated Seneca and Gathering IRR is pre-tax and includes expected gathering capital expenditures, well costs under current cost structure, and non-gathering LOE.
$0
$50
$100
$150
$200
$2.25 $2.50 $2.75 $3.00
Free
Cas
h Fl
ow ($
Mill
ions
)(1)
$95-$105
$140-$150
$50-$60
@ NYMEX Price ($/MMBtu)
$185-$195Seneca and Gathering Consolidated Economics (Realized Price is NYMEX less applicable transport charges)
Significant Free Cash Flow Generation Expected at Prices
Below Current NYMEX Strip
COVER
FY19 Q4 Investor Relations Packet
05/04/2020
Model Inputs
WDA Utica
xyy
DurationCost
70 wells700.9460.928
120 wells1200.8820.886
100 wells1000.90760.9028
DCNR 007 Utica
xyy
DurationCost
20 wells201.081
70 wells701.0220.975
43 wells431.053320.9885
PadAreaMarcUtica $/bbl 1019$/bblAve Well #
CRV D09-D2 UWDA4$2.00MarcWDA2.1565
DCNR 100 M3 MLycoming2$1.75MarcLycoming2.3114
HEMLOCK E09-S2WDA6$2.00UticaDCNR 0072.0006
CRV C08-X2 UWDA6$2.70UticaWDA2.2125
DCNR 100 R2 MLycoming5$1.80
HEMLOCK E09-UWDA42$1.75
GAMBLE J Lycoming5$3.25
CRV C09-G2 UWDA6$1.600719$/bblAve Well #Water Delta
GAMBLE K2 MLycoming8$3.50MarcWDA2.12570.031
HEMLOCK E09-T2 MWDA4$2.25MarcLycoming2.21750.094
CRV D08-O2 UWDA4$2.25UticaDCNR 0071.56350.438
CRV D08-U2 UWDA4$2.25UticaWDA1.67160.541
WEST BRANCH E08-L2 UWDA6$2.25
DCNR 007 D UDCNR 0076$2.00
CRV E09-E2 UWDA5$2.25
Boone Mtn. F14-COP-I UWDA1$2.25
CRV C08-G2 UWDA4$2.25
HEMLOCK F10-F2WDA82$2.25
GAMBLE A2 MLycoming5$2.00
CRV C09-D3WDA35$2.25
GAMBLE GLycoming4$2.50
HEMLOCK E09-U2 MWDA8$2.25
BEECHWOOD B09-I UWDA7$2.25
GAMBLE OLycoming5$2.00
BEECHWOOD C09-J UWDA5$2.25
CRV D09-M UWDA5$2.25
HEMLOCK E09-T3 UWDA6$2.25
GAMBLE J2 MLycoming4$2.00
CRV E08-T2 UWDA5$2.25
HEMLOCK E09-J2 UWDA4$2.25
CRV D08-N2 UWDA6$2.25
HEMLOCK F10-F3 UWDA4$2.25
HEMLOCK E09-U3WDA38$2.25
GAMBLE P2 MLycoming2$2.00
CRV D09-M2 UWDA7$2.25
CRV D08-M2WDA26$2.25
BEECHWOOD C09-Q UWDA7$2.25
HEMLOCK E09-S3 UWDA4$2.25
Lycoming
AREA INFORMATION
PROSPECTLycoming*DCNR 100 & Gamble comboTest Month09/2020
COUNTYLycomingGross Gas Prod, MMcf (shrunk)2386.91
Avg Wells per Pad5*from planningGross Gas Prod, MMcf (unshrunk)2391.69Frac$1,557,400drill duration16.2373940763
Net Var Exp, M$$1,316.70Drillout$360,570
ECONOMIC ASSUMPTIONSNet Fix Exp, M$$11.93Toe Prep$87,000
BTU (mmBTU/mcf)1.03112*in LOE sheet, ARIES inputsNet Tot Exp, M$$1,328.62Flowback$218,200W/ Water
FIXED LOE ($/month/well)$994Actual Gas Price, $/Mcf$2.000Sum Total Compl$2,223,170$2,692,326
VARIABLE LOE ($/mcf)$0.036Net Gas Price, $/Mcf$2.062Water$469,156
MIDSTREAM FEE ($/mcf)$0.516*$0.50 transport feeNet Gas Revenue. M$$4,134.80
WATER DISPOSAL LOE ($/well, 1 time fee)$0*water disposal cost removed
PRICING (Realized)$2.50 / $2.25 / $2.00
BASIS DIFFERENTIAL($0.730)
SHRINKAGE %0.20.998
IMPACT FEESPUD_2019*sames as start date
CAPITAL (and Timing)ARIES EntriesValuesCapitalModel(s) Used
DRILLING (-6 Months)$2,211,350*drill capital x efficiencies + rig move/#wellsDRILLING (-6 Months)2211.350DRILLING (-6 Months)DCNR 100 Marc, No Capital Efficiency
COMPLETION (-2 Months)$2,583,308*frac + drillout + toe prep + flowback + waterCOMPLETION (-2 Months)2583.308COMPLETION (-2 Months)used components: DCNR 100/Gamble 200' stg
PRODUCTION (-1 Month)$426,000PRODUCTION (-1 Month)426.000PRODUCTION (-1 Month)EDA 5-7 wells
PAD (-7 Months)$440,000*from planningPAD (-7 Months)440.000PAD (-7 Months)Provided by Planning
TOTAL CAPEX$5,660,657TOTAL CAPEX5660.657
TREATED LENGTH (FT)5,800*per KWMUL Factor1.07411.056
STAGE LENGTH200
OWNERSHIP
WI (%)100
NRI (%)84
TIMING ASSUMPTIONSTYPE CURVE - 5,400' 13,534 MMcf
Production start date of 05/2020*current month + 7 months16706XM/D1.84MOSB/1.276.5
See CAPITAL section for CAPEX timings (relative to production start)*report date = current quarter10627XM/D16.16IMOSB/1.145
6603XM/D6EXPB/.743.8
RESERVESX30M/DXIMOSEXP6
P50 EUR/1000'2.70 BCF/1000'*in TC sheet
P50 EUR15.65 BCF17943.481XM/D1.84MOSB/1.276.5
11414.185XM/D16.16IMOSB/1.145
7092.111XM/D6EXPB/.743.8
X30M/DXIMOSEXP6
2.702037037NEW TYPE CURVE - 5,400' 14,591 MMcf (18 month compression)
15671.8148148148162004788.4M/D18MOSB/2.265
6224XM/D6EXPB/1.041.5
X30M/DXIMOSEXP 6
17400.0005143.096M/D18MOSB/2.265
6685.037XM/D6EXPB/1.041.5
X30M/DXIMOSEXP 6
2.6983333333NEW TYPE CURVE - 5,400' 14,571 MMcf (12 month compression)
15650.3333333333162005670M/D12MOSB/2.265
7371XM/D6EXPB/1.044.5
X30M/DXIMOSEXP 6
17400.0006090.000M/D12MOSB/2.265
7917.000XM/D6EXPB/1.044.5
X30M/DXIMOSEXP 6
DCNR 007 - Tioga Utica
AREA INFORMATION
PROSPECTDCNR 007 UticaTest Month
COUNTYTiogaGross Gas Prod, MMcf (shrunk)3109.73
Avg Wells per Pad6Gross Gas Prod, MMcf (unshrunk)3173.193877551Frac$3,605,280drill duration29.6562218316
Net Var Exp, M$$1,693.36Drillout$634,005
ECONOMIC ASSUMPTIONSNet Fix Exp, M$$11.93Toe Prep$107,000
BTU (mmBTU/mcf)1.01560*in LOE sheet, ARIES inputsNet Tot Exp, M$$1,705.28Flowback$392,600
FIXED LOE ($/month/well)$994Actual Gas Price, $/Mcf$2.000Water$928,000
VARIABLE LOE ($/mcf)$0.036Net Gas Price, $/Mcf$2.031Total w/ 200' stg$5,666,885
MIDSTREAM FEE ($/mcf)$0.508*$0.50 transport feeNet Gas Revenue. M$$5,179.52
WATER DISPOSAL LOE ($/well, 1 time fee)$0*water disposal cost removed
PRICING (Realized)$2.50 / $2.25 / $2.00
BASIS DIFFERENTIAL($0.695)
SHRINKAGE %2.00.98
IMPACT FEESPUD_2019*sames as start date
CAPITAL (and Timing)ARIES EntriesValuesCapitalModel(s) Used
DRILLING (-6 Months)$3,492,515*drill capital x efficiencies + rig movesDRILLING (-6 Months)3492.515DRILLING (-6 Months)007/Boone Mtn Utica, 43 well capital efficiency (0.97286)
COMPLETION (-2 Months)$5,414,515*frac + drillout + toe prep + flowback + waterCOMPLETION (-2 Months)5414.515COMPLETION (-2 Months)used components: Various Utica 200' stg
PRODUCTION (-1 Month)$426,000PRODUCTION (-1 Month)426.000PRODUCTION (-1 Month)EDA 5-7 wells
PAD (-7 Months)$366,667*from planningPAD (-7 Months)366.667PAD (-7 Months)Provided by Planning
TOTAL CAPEX$9,699,697TOTAL CAPEX9849.697
TREATED LENGTH (FT)8,700MUL Factor1.16001.13
STAGE LENGTH150
OWNERSHIP
WI (%)100
NRI (%)82
TYPE CURVE - 7,500' 15,212 MMcf
TIMING ASSUMPTIONS
Production start date of 05/2020*current month + 7 months
See CAPITAL section for CAPEX timings (relative to production start)*report date = current quarter
RESERVES
P50 EUR/1000'2.25 BCF/1000'*in TC sheet
P50 EUR19.57 BCF*in TC sheetSTARTNov-18
GAS1941019410M/D2MOEXPX
"21000XM/D6EXPB/172
"X30M/DXYRSEXP6
DCNR 100
AREA INFORMATION
PROSPECTDCNR 100Test Month
COUNTYLycomingGross Gas Prod, MMcf (shrunk)2788.3
Avg Wells per Pad4.4444444444Gross Gas Prod, MMcf (unshrunk)2822.1659919028Frac$1,631,200
Net Var Exp, M$$1,525.13Drillout$221,920
ECONOMIC ASSUMPTIONSNet Fix Exp, M$$15.17Toe Prep$60,000
BTU (mmBTU/mcf)1.03120*in LOE sheet, ARIES inputsNet Tot Exp, M$$1,540.30Flowback$40,000W/ Water
FIXED LOE ($/month/well)$1,264Actual Gas Price, $/Mcf$2.000Sum Total Compl$1,953,120$2,355,253
VARIABLE LOE ($/mcf)$0.031Net Gas Price, $/Mcf$1.031Calc Total Compl$2,040,420$2,442,553
MIDSTREAM FEE ($/mcf)$0.516*$0.50 transport feeNet Gas Revenue. M$$2,875.29Water$402,133
WATER DISPOSAL LOE ($/well, 1 time fee)$29,885
PRICING (Realized)$2.50 / $2.25 / $2.00
BASIS DIFFERENTIAL($0.730)
SHRINKAGE %1.2
IMPACT FEESPUD_2018*sames as start date
CAPITAL (and Timing)ARIES EntriesValuesCapitalModel(s) Used
DRILLING (-6 Months)$1,726,811DRILLING (-6 Months)1726.811DRILLING (-6 Months)DCNR 100 Marc, 2018 Capital Efficiency (1.00)
COMPLETION (-2 Months)$2,355,253COMPLETION (-2 Months)2355.253COMPLETION (-2 Months)used components: Model 7, RCS 10K 200' stg WDA or DCNR 595 6 stg/day
PRODUCTION (-1 Month)$426,000PRODUCTION (-1 Month)426.000PRODUCTION (-1 Month)DCNR 100 5 well
PAD (-7 Months)$495,000PAD (-7 Months)495.000PAD (-7 Months)$2.2MM split out by well
TOTAL CAPEX$5,003,065TOTAL CAPEX5153.065
TREATED LENGTH (FT)5,600*from geoMUL Factor1.03701.018
STAGE LENGTH190
OWNERSHIP
WI (%)100
NRI (%)84
TIMING ASSUMPTIONS
Production start date of 08/2018*current month + 7 months
See CAPITAL section for CAPEX timings (relative to production start)*report date = current quarter
RESERVES
P50 EUR/1000'2.49 BCF/1000'*in TC sheet
P50 EUR13.95 BCF
CRV Marcellus
AREA INFORMATION
PROSPECTCore Areas*CRV/Hemlock/RidgewayTest Month
COUNTYVariousGross Gas Prod, MMcf (shrunk)984.4150'
Avg Wells per Pad5*from planningGross Gas Prod, MMcf (unshrunk)993.3400605449Frac$2,851,900drill duration10.3601820412
Net Var Exp, M$$597.50Drillout$429,900
ECONOMIC ASSUMPTIONSNet Fix Exp, M$$4.34Toe Prep$84,000
BTU (mmBTU/mcf)1.04120*in LOE sheet, ARIES inputsNet Tot Exp, M$$601.84Flowback$80,000W/ Water
FIXED LOE ($/month/well)$362Actual Gas Price, $/Mcf$2.000Sum Total Compl$3,445,800$4,027,988
VARIABLE LOE ($/mcf)$0.034Net Gas Price, $/Mcf$2.082Water$582,188
MIDSTREAM FEE ($/mcf)$0.573*$0.55 transport feeNet Gas Revenue. M$$2,049.91
WATER DISPOSAL LOE ($/well, 1 time fee)$0*water disposal cost removed
PRICING (Realized)$2.50 / $2.25 / $2.00
BASIS DIFFERENTIAL($0.770)
SHRINKAGE %0.90.991
IMPACT FEESPUD_2019*sames as start date
CAPITAL (and Timing)ARIES EntriesValuesCapitalModel(s) Used
DRILLING (-6 Months)$1,655,874*drill capital x efficiencies + rig movesDRILLING (-6 Months)1655.874DRILLING (-6 Months)WDA Marc, No Capital Efficiency
COMPLETION (-2 Months)$3,828,355*frac + drillout + toe prep + flowback + waterCOMPLETION (-2 Months)3828.355COMPLETION (-2 Months)used components: Hemlock Marc 200' stg
PRODUCTION (-1 Month)$260,000PRODUCTION (-1 Month)260.000PRODUCTION (-1 Month)WDA Bulk 7-10 wells
PAD (-7 Months)$180,000PAD (-7 Months)180.000PAD (-7 Months)Provided by planning
TOTAL CAPEX$5,924,228TOTAL CAPEX6074.228
TREATED LENGTH (FT)9,000*from geo - adjustedMUL Factor1.20000.99
STAGE LENGTH150
OWNERSHIP
WI (%)100$0.658
NRI (%)1000.0466666667
TIMING ASSUMPTIONSTYPE CURVE - 8,500' 8,885 MMcf
Production start date of 05/2020*current month + 7 monthsGAS8075XM/D1MOSB/459
See CAPITAL section for CAPEX timings (relative to production start)*report date = current quarter"5758.75XM/D23IMOSB/257
"1873.4XM/D4.8791EXPB/119
RESERVES"X30M/DXIMOSEXP4.8791
P50 EUR/1000'1.15 BCF/1000'*not in TC sheet
P50 EUR10.35 BCF
Core Areas
AREA INFORMATION
PROSPECTCore Areas*CRV/Hemlock/RidgewayTest Month
COUNTYVariousGross Gas Prod, MMcf (shrunk)984.4150'
Avg Wells per Pad5*from planningGross Gas Prod, MMcf (unshrunk)993.3400605449Frac$2,700,000drill duration10.1458747721
Net Var Exp, M$$597.50Drillout$417,850
ECONOMIC ASSUMPTIONSNet Fix Exp, M$$4.34Toe Prep$84,000
BTU (mmBTU/mcf)1.04120*in LOE sheet, ARIES inputsNet Tot Exp, M$$601.84Flowback$80,000W/ Water
FIXED LOE ($/month/well)$362Actual Gas Price, $/Mcf$2.000Sum Total Compl$3,281,850$3,825,225
VARIABLE LOE ($/mcf)$0.034Net Gas Price, $/Mcf$2.082Water$543,375
MIDSTREAM FEE ($/mcf)$0.573*$0.55 transport feeNet Gas Revenue. M$$2,049.91
WATER DISPOSAL LOE ($/well, 1 time fee)$0*water disposal cost removed
PRICING (Realized)$2.50 / $2.25 / $2.00
BASIS DIFFERENTIAL($0.770)
SHRINKAGE %0.90.991
IMPACT FEESPUD_2019*sames as start date
CAPITAL (and Timing)ARIES EntriesValuesCapitalModel(s) Used
DRILLING (-6 Months)$1,606,988*drill capital x efficiencies + rig movesDRILLING (-6 Months)1606.988DRILLING (-6 Months)WDA Marc, No Capital Efficiency
COMPLETION (-2 Months)$3,636,225*frac + drillout + toe prep + flowback + waterCOMPLETION (-2 Months)3636.225COMPLETION (-2 Months)used components: Hemlock Marc 200' stg
PRODUCTION (-1 Month)$260,000PRODUCTION (-1 Month)260.000PRODUCTION (-1 Month)WDA Bulk 7-10 wells
PAD (-7 Months)$440,000PAD (-7 Months)440.000PAD (-7 Months)Provided by planning
TOTAL CAPEX$5,943,213TOTAL CAPEX6093.213
TREATED LENGTH (FT)8,500*from geo - adjustedMUL Factor1.13330.99
STAGE LENGTH150
OWNERSHIP$1.21
WI (%)100$1.47
NRI (%)100
TIMING ASSUMPTIONSTYPE CURVE - 8,500' 8,885 MMcf
Production start date of 05/2020*current month + 7 monthsGAS8075XM/D1MOSB/459
See CAPITAL section for CAPEX timings (relative to production start)*report date = current quarter"5758.75XM/D23IMOSB/257
"1873.4XM/D4.8791EXPB/119
RESERVES"X30M/DXIMOSEXP4.8791
P50 EUR/1000'1.08 BCF/1000'*not in TC sheet
P50 EUR9.18 BCF
Rich Valley Utica
AREA INFORMATION
PROSPECTCRV UticaTest Month09/2020
COUNTYVariousGross Gas Prod, MMcf (shrunk)1514.85200'
Avg Wells per Pad5Gross Gas Prod, MMcf (unshrunk)1528.6074672048Frac$3,201,600drill duration24.2008243446
Net Var Exp, M$$948.47Drillout$534,950
ECONOMIC ASSUMPTIONSNet Fix Exp, M$$4.34Toe Prep$107,000
BTU (mmBTU/mcf)1.02281*in LOE sheet, ARIES inputsNet Tot Exp, M$$952.82Flowback$393,200W/ Water
FIXED LOE ($/month/well)$362Actual Gas Price, $/Mcf$2.000Sum Total Compl$4,236,750$5,232,150
VARIABLE LOE ($/mcf)$0.063Net Gas Price, $/Mcf$2.046Water$995,400
MIDSTREAM FEE ($/mcf)$0.563*$0.55 transport feeNet Gas Revenue. M$$3,098.81
WATER DISPOSAL LOE ($/well, 1 time fee)$0*water disposal cost removed
PRICING (Realized)$2.50 / $2.25 / $2.00
BASIS DIFFERENTIAL($0.770)
SHRINKAGE %0.90.991
IMPACT FEESPUD_2019*sames as start date
CAPITAL (and Timing)ARIES EntriesValuesCapitalModel(s) Used
DRILLING (-5 Months)$3,007,356*drill capital x efficiencies + rig movesDRILLING (-6 Months)3007.356DRILLING (-6 Months)WDA Utica, 100 well Capital Efficiency
COMPLETION (-2 Months)$5,008,038*frac + drillout + toe prep + flowback + waterCOMPLETION (-2 Months)5008.038COMPLETION (-2 Months)used components: Various Utica 200' stg
PRODUCTION (-1 Month)$352,148*Prod + Fresh Wtr InjPRODUCTION (-1 Month)352.148PRODUCTION (-1 Month)WDA Bulk Utica 7-10 well + Fresh Water Injection Capital for 5 well pad
PAD (-6 Months)$440,000180000PAD (-7 Months)440.000PAD (-7 Months)Provided by planning
TOTAL CAPEX$8,807,542TOTAL CAPEX8807.542
TREATED LENGTH (FT)9,000*from geoMUL Factor1.20001.1843
STAGE LENGTH200
OWNERSHIP
WI (%)100
NRI (%)100
TYPE CURVE - 1,200' spacing, Q419
TIMING ASSUMPTIONS
Production start date of 05/2020*current month + 7 monthsSegmentStart RateEnd RateUnitsDurationDecline Type & ExponentDecline Rate
See CAPITAL section for CAPEX timings (relative to production start)*report date = current quarter101M/D0.75MOSSPDX
21XM/D1IMOSFLAT0
RESERVES31XM/D12IMOSB/246
P50 EUR/1000'1.73 BCF/1000'50XM/D4.8558EXPB/1.227.4
P50 EUR15.61 BCF6X30M/DXIMOSEXP4.8558
18007650M/D0.75MOSSPDX
7650XM/D1IMOSFLAT0
7650XM/D12IMOSB/246
4131XM/D4.8558EXPB/1.227.4
X30M/DXIMOSEXP4.8558
RV-Boone Mt Utica
AREA INFORMATION
PROSPECTCRV UticaTest Month09/2020
COUNTYVariousGross Gas Prod, MMcf (shrunk)1514.85200'
Avg Wells per Pad5Gross Gas Prod, MMcf (unshrunk)1528.6074672048Frac$3,201,600drill duration24.2008243446
Net Var Exp, M$$948.47Drillout$534,950
ECONOMIC ASSUMPTIONSNet Fix Exp, M$$4.34Toe Prep$107,000
BTU (mmBTU/mcf)1.02281*in LOE sheet, ARIES inputsNet Tot Exp, M$$952.82Flowback$393,200W/ Water
FIXED LOE ($/month/well)$362Actual Gas Price, $/Mcf$2.000Sum Total Compl$4,236,750$5,232,150
VARIABLE LOE ($/mcf)$0.063Net Gas Price, $/Mcf$2.046Water$995,400
MIDSTREAM FEE ($/mcf)$0.563*$0.55 transport feeNet Gas Revenue. M$$3,098.81
WATER DISPOSAL LOE ($/well, 1 time fee)$0*water disposal cost removed
PRICING (Realized)$2.50 / $2.25 / $2.00
BASIS DIFFERENTIAL($0.770)
SHRINKAGE %0.90.991
IMPACT FEESPUD_2019*sames as start date
CAPITAL (and Timing)ARIES EntriesValuesCapitalModel(s) Used
DRILLING (-5 Months)$3,007,356*drill capital x efficiencies + rig movesDRILLING (-6 Months)3007.356DRILLING (-6 Months)WDA Utica, 100 well Capital Efficiency
COMPLETION (-2 Months)$5,008,038*frac + drillout + toe prep + flowback + waterCOMPLETION (-2 Months)5008.038COMPLETION (-2 Months)used components: Various Utica 200' stg
PRODUCTION (-1 Month)$352,148*Prod + Fresh Wtr InjPRODUCTION (-1 Month)352.148PRODUCTION (-1 Month)WDA Bulk Utica 7-10 well + Fresh Water Injection Capital for 5 well pad
PAD (-6 Months)$440,000180000PAD (-7 Months)440.000PAD (-7 Months)Provided by planning
TOTAL CAPEX$8,807,542TOTAL CAPEX8807.542
TREATED LENGTH (FT)9,000*from geoMUL Factor1.20001.1843
STAGE LENGTH200
OWNERSHIP
WI (%)100
NRI (%)100
TYPE CURVE - 1,200' spacing, Q419
TIMING ASSUMPTIONS
Production start date of 05/2020*current month + 7 monthsSegmentStart RateEnd RateUnitsDurationDecline Type & ExponentDecline Rate
See CAPITAL section for CAPEX timings (relative to production start)*report date = current quarter101M/D0.75MOSSPDX
21XM/D1IMOSFLAT0
RESERVES31XM/D12IMOSB/246
P50 EUR/1000'1.82 BCF/1000'50XM/D4.8558EXPB/1.227.4
P50 EUR16.40 BCF6X30M/DXIMOSEXP4.8558
18007650M/D0.75MOSSPDX
7650XM/D1IMOSFLAT0
7650XM/D12IMOSB/246
4131XM/D4.8558EXPB/1.227.4
X30M/DXIMOSEXP4.8558
Hemlock - West Branch Utica
AREA INFORMATION
PROSPECTCRV UticaTest Month09/2020
COUNTYVariousGross Gas Prod, MMcf (shrunk)1514.85200'
Avg Wells per Pad5Gross Gas Prod, MMcf (unshrunk)1528.6074672048Frac$3,372,700drill duration25.00578795
Net Var Exp, M$$948.47Drillout$553,075
ECONOMIC ASSUMPTIONSNet Fix Exp, M$$4.34Toe Prep$107,000
BTU (mmBTU/mcf)1.02281*in LOE sheet, ARIES inputsNet Tot Exp, M$$952.82Flowback$393,200W/ Water
FIXED LOE ($/month/well)$362Actual Gas Price, $/Mcf$2.000Sum Total Compl$4,425,975$5,361,651
VARIABLE LOE ($/mcf)$0.063Net Gas Price, $/Mcf$2.046Water$935,676
MIDSTREAM FEE ($/mcf)$0.563*$0.55 transport feeNet Gas Revenue. M$$3,098.81
WATER DISPOSAL LOE ($/well, 1 time fee)$0*water disposal cost removed
PRICING (Realized)$2.50 / $2.25 / $2.00
BASIS DIFFERENTIAL($0.770)
SHRINKAGE %0.90.991
IMPACT FEESPUD_2019*sames as start date
CAPITAL (and Timing)ARIES EntriesValuesCapitalModel(s) Used
DRILLING (-5 Months)$2,735,634*drill capital x efficiencies + rig movesDRILLING (-6 Months)2735.634DRILLING (-6 Months)WDA Utica, 100 well Capital Efficiency
COMPLETION (-2 Months)$5,125,562*frac + drillout + toe prep + flowback + waterCOMPLETION (-2 Months)5125.562COMPLETION (-2 Months)used components: Various Utica 200' stg
PRODUCTION (-1 Month)$352,148*Prod + Fresh Wtr InjPRODUCTION (-1 Month)352.148PRODUCTION (-1 Month)WDA Bulk Utica 7-10 well + Fresh Water Injection Capital for 5 well pad
PAD (-6 Months)$180,000180000PAD (-7 Months)180.000PAD (-7 Months)Provided by planning
TOTAL CAPEX$8,393,344TOTAL CAPEX8393.344
TREATED LENGTH (FT)9,500*from geoMUL Factor1.26671.1843
STAGE LENGTH200
OWNERSHIP
WI (%)100
NRI (%)100
TYPE CURVE - 1,200' spacing, Q419
TIMING ASSUMPTIONS
Production start date of 05/2020*current month + 7 monthsSegmentStart RateEnd RateUnitsDurationDecline Type & ExponentDecline Rate
See CAPITAL section for CAPEX timings (relative to production start)*report date = current quarter101M/D0.75MOSSPDX
21XM/D1IMOSFLAT0
RESERVES31XM/D12IMOSB/246
P50 EUR/1000'1.62 BCF/1000'50XM/D4.8558EXPB/1.227.4
P50 EUR15.38 BCF6X30M/DXIMOSEXP4.8558
19008075M/D0.75MOSSPDX
8075XM/D1IMOSFLAT0
8075XM/D12IMOSB/246
4360.5XM/D4.8558EXPB/1.227.4
X30M/DXIMOSEXP4.8558
Sheet1
9K Q39K Q4IR Q3IR Q4
00.01679882980.01679882980.02336391130.0172836988
10.03915017460.03781140970.05091333280.0426968661
20.06259734420.05776837330.07803916610.0672299669
30.08377965740.07525710840.10149202140.0898237404
40.10438538550.09207933340.1236035240.1095586515
50.12327981650.10738642520.14340591810.1294226497
60.14187758520.12235976150.16254252040.1476241213
70.159656780.13660002620.18056475310.1655295665
80.17617685740.14977556960.19710939290.1820981345
90.19261802920.16284096490.21340963060.1985297589
100.20798208210.17501257930.22851186320.2143395662
110.22334808360.18715302650.24350518750.2291092649
120.23824275110.19889291730.25794444170.2438770424
130.25171153550.21042451860.27121974430.2577318492
140.26727869460.22312205390.28600343120.2716044046
150.28153194680.23497507630.29960102240.2850462224
160.29557825760.24681859570.31304639520.2968406469
170.30861849040.25792474950.32556128650.3095387265
180.32160688090.26906627560.33805577590.3214882218
190.33419427490.27989577070.3501886460.3335064488
200.34603460560.29010224850.36161446490.3448360942
210.3579383360.30038730930.37311374210.356249722
220.36915588610.31010526680.38396102850.3673809366
230.38045265510.31992054240.394895220.3778982577
240.39146623510.32952048620.40556493370.3885162354
250.40152633820.33832732410.4153189770.3985616854
260.41203380330.34758750260.42551471080.408715763
270.42197175090.35640356320.4351650640.41865071
280.43201434220.36536853230.444923970.4274443137
290.44152398730.37390881830.45417122850.4369896351
300.4511446750.38259852050.46353247080.4460445403
310.46056550450.39115532120.47270493570.4552207389
320.46950054360.3993136940.48140948010.4639334291
330.47855356110.40762159340.49023385320.4727705177
340.48714774260.41554672610.498615420.4814455927
350.49586312920.42362111560.50711949950.4896925936
360.5044173010.43158227160.51547038510.4980671779
370.51201042890.43867852780.52288639780.5060343339
380.5202751830.44643353510.53096184940.5141304138
390.52813652830.45383962480.53864642150.5220926043
400.53612379450.46139345980.54645729250.5291731578
410.543726410.46861037340.55389494610.5368935078
420.55145589210.47597417080.56145958690.5442498304
430.55906124140.48324535840.5689055090.551736518
440.56630712050.49019619310.5760019950.5588741678
450.57368055920.49729242050.58322586170.5661422068
460.58070946010.50407838420.59011443460.573304414
470.58786599750.51100865350.59713031210.580137956
480.59491758620.51785780730.60404544730.5871014927
490.60119932830.52397613430.61020739130.5937485849
500.60806023510.53067653140.61693931210.600525185
510.61460865160.53708902230.62336639320.6072109438
520.62128395360.5436428980.6299197610.6133854615
530.62765804920.54991697960.63617904530.6199027855
540.6341584460.55633120260.64256395780.6261304166
550.64057375640.56267692960.64886685330.6324857839
560.64670338070.56875423550.65489048940.6385609312
570.65295820880.57496976640.66103857080.6447629398
580.65893676530.58092389990.66691640130.6508900845
590.66503968590.58701497040.6729177950.6567501454
600.67106847040.59304486490.67884754880.6627356258
610.67645172850.59843975130.68414342360.6684620518
620.68234474510.60435686730.68994189390.6743128793
630.68798225420.61002842510.69549002660.6800977943
640.69374178130.61583370840.70115930720.6852675675
650.69925330140.62139927650.70658545870.6909314391
660.70488581540.62709727390.71213171710.6963541324
670.71045611050.63274240120.71761767580.701898568
680.71578888370.63815609360.72287059630.7072083401
690.72124105360.64370027130.72824200970.712638744
700.72646215980.64901818080.73338660790.7180131489
710.73180157880.65446529720.73864860910.7231620498
720.73708563840.65986450410.74385686220.7284298869
730.74197977910.66487281530.7486814980.733477892
740.74716019630.67018187640.75378907620.7386437021
750.75212415380.67527654470.75868393430.7437593081
760.75720367920.68049728430.76369344770.7483375871
770.76207207720.68550803540.76849539560.753360546
780.76705493490.69064362270.77341089310.758176507
790.77199019870.69573709470.77828008190.7631074744
800.77672187620.70062687070.78294900220.7678361937
810.78156634510.70563964840.78772981070.7726787964
820.78621192360.71045268660.79231489890.7774778124
830.7909691930.71538752990.79701078120.7820813254
840.79568345610.72028377870.80166476180.786797043
850.79990523970.72467357180.80583301920.7913214747
860.80453996870.72949816980.81040947980.7959570099
870.80898650740.73413215620.81480059590.8005529337
880.81354204640.73888505680.81929983520.8046706574
890.81791338170.7434507870.82361760.8091932107
900.82239264780.74813429330.82804242780.813534136
910.82683421750.75278337980.83243046650.8179834887
920.83109726960.75725024330.83664255520.8222548289
930.83546666160.76183319870.84096013060.8266335378
940.83966110620.76623706090.8451052270.830977282
950.84396085180.770755920.84935478140.8351481874
960.84822612970.77524295450.85357066220.8394248911
970.85204951420.7792688130.85735009540.8435320143
980.85625084240.78369661960.86150348150.8477439125
990.86028544280.78795260950.86549238750.8519236966
1000.86442283090.79232095980.86958326480.8558052173
1010.86839658420.79652025730.87351267470.8599243497
1020.87247213470.80083087980.8775430760.8638814806
1030.87651703130.80511280310.88154349030.8679409008
1040.88040273450.80922966710.88538676570.8718411626
1050.88438876810.81345632660.88932958250.8758427424
1060.88821841440.81752046540.89311799680.8798156165
1070.89214743730.82169340620.89700500950.8836334248
1080.89604816870.82583961840.90086432260.8875511147
1090.89954746260.82956192140.90432670390.891316331
1100.90339556770.83365828890.90813447960.8951804955
1110.90709379920.83759807490.91179420960.8990180697
1120.91088910920.84164427370.91555026690.9024617431
1130.91453701630.84553616080.91916069110.9062498053
1140.91828109920.84953352320.92286655070.9098914304
1150.92199972650.85350656020.92654746070.9136297568
1160.92557451680.85732857830.93008622180.9172239424
1170.92924414880.86125468710.93371910010.9209139473
1180.93277220830.86503187840.93721204320.9245799176
1190.93639424310.86891226130.94079824750.9281050686
1200.93999260540.87276985210.94436123370.9317247359
1210.94333768360.87635819150.9476736210.9352056974
1220.94689118090.88017249440.95119259470.9387803291
1230.95030843080.88384285330.95457684130.9423325425
1240.95381755810.88761422750.9580522770.9455219798
1250.95719245650.89124355480.9613949610.949032369
1260.96065841470.89497304910.96482802640.9524090035
1270.96410287870.89868164950.96823999150.9558772734
1280.96741603980.90225096480.97152206970.959213683
1290.97081905310.90591919380.97489333630.9626409297
1300.97409262940.90944990610.97813654350.9660477345
1310.97745527370.9130787180.98146816460.9693254299
1320.98079780330.91668785290.9847800280.972692783
1330.9837997920.91993099810.98775461950.9759327838
1340.98710476060.92350332410.99102958260.9792616765
1350.99028467560.92694231010.99418078170.9825713915
1360.99355177280.9304774370.99741853180.9855445287
1370.99669549830.93388083461.0005341670.9888184072
1380.99992566590.93737960411.0037356210.9919690696
1391.0031374150.940860211.0069189720.9952067823
1401.006228240.94421143841.0099826060.9983228694
1411.0094044130.94765690171.013130981.001525284
1421.0124612270.95097449761.0161611741.004710082
1431.015602680.95438558961.0192754071.007775571
1441.0187268050.95777950151.0223725991.01092632
1451.0215338770.9608303611.0251555861.013959244
1461.0246255990.96419209521.0282209061.017076734
1471.0276016560.96742954151.0311716721.020177616
1481.0306606440.97075870491.0342047891.023063577
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