Non-Operated Working Interest Assets in the Williston Basin March - - PowerPoint PPT Presentation

non operated working interest assets in the williston
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Non-Operated Working Interest Assets in the Williston Basin March - - PowerPoint PPT Presentation

Non-Operated Working Interest Assets in the Williston Basin March 2018 S ALES P ROCESS O VERVIEW | C ONTACT I NFORMATION P RESENTATION O UTLINE S ALES P ROCESS O VERVIEW Key Dates Preliminary Bid Instructions I. Executive Summary


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Non-Operated Working Interest Assets in the Williston Basin

March 2018

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Confidential – Not For Distribution 2

SALES PROCESS OVERVIEW | CONTACT INFORMATION

EAGLE RIVER A&D TEAM SALES PROCESS OVERVIEW

Key Dates ▪ Effective Date April 1, 2018 ▪ VDR opened March 27, 2018 ▪ VDR access March 27 – April 26, 2018

PRESENTATION OUTLINE

I. Executive Summary II. Land Overview

  • III. Geology Overview
  • IV. Reservoir Engineering Overview

V. Asset Summary

Preliminary Bid Instructions ▪ Bids due April 26, 2018 Austin McKee

Managing Director Austin@EagleRiverHoldingsLLC.com 303-832-5128

Brian Green

Managing Director Brian@EagleRiverHoldingsLLC.com 832-680-0110

Darrell Finneman

Managing Director Darrell@EagleRiverHoldingsLLC.com 720-726-6091

James Barnes

Director James@EagleRiverHoldingsLLC.com 832-680-0112

Alex Sale

Director of Engineering Alex@EagleRiverHoldingsLLC.com 720-726-6094

Kari Bleyle

Manager Kari@EagleRiverHoldingsLLC.com 303-770-6096

Kit Reasoner

Reservoir Engineering Analyst Kathryn@EagleRiverHoldingsLLC.com 720-726-6092

Denver Office

5460 S Quebec St Ste 335 Greenwood Village, CO 80111

Houston Office

25700 I-45 North, Suite 400 The Woodlands, TX 77386 VDR Available Holidays Evaluation/Data Rooms Bids Due

S M T W T F S S M T W T F S 1 2 3 1 2 3 4 5 6 7 4 5 6 7 8 9 10 8 9 10 11 12 13 14 11 12 13 14 15 16 17 15 16 17 18 19 20 21 18 19 20 21 22 23 24 22 23 24 25 26 27 28 25 26 27 28 29 30 31 29 30

March April

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Confidential – Not For Distribution 3

Eagle River Holdings, LLC has been exclusively retained by Holt Production, LLC (“Seller”) for the divestiture of non-operated working interest assets and associated development rights located in the Williston Basin of Billings and Stark Counties, North Dakota.

▪ ~2,908 MBOE total net Proved Reserves (16% developed / 84% undeveloped) ▪ ~180 BOEPD net production (65% Oil / 19% Gas / 16% NGL) ▪ ~$178,000 monthly operating income (3-mo average) with above WTI realized oil prices ▪ 2 DUC wells anticipated online in 2018 adding ~$37,000 monthly net operating income ▪ ~1,961 net and ~66,854 gross acres ▪ 128 producing wells (3.2% WI / 2.7% NRI average) ▪ 2 DUC wells under Whiting Petroleum (1) and Thunderbird Resources (1) ▪ 12 active permits with development timeline proposed by Whiting Petroleum with 104 additional PUD locations identified ▪ ~444 MBOE PDP net Reserves ▪ ~32 MBOE DUC net Reserves with completions anticipated in 2018 ▪ ~2,432 MBOE PUD net Reserves ▪ Unquantified upside associated with horizontal Three Forks second and third bench formation targets ▪ Predictable production and revenue stream given the majority of the wells have entered terminal decline ▪ Operated predominantly by top Basin operator, Whiting Petroleum Corporation ▪ Primary Target: Three Forks / Pronghorn ▪ Significant drilling inventory with additional upside in NexGen D&C techniques utilizing higher proppant density and plug & perf designs allowing higher pump rates

  • I. EXECUTIVE SUMMARY

Non-Operated Working Interest Assets for Sale in the Williston Basin

NON-OPERATED POSITION UNDER PLANNED DEVELOPMENT BLOCKED ACREAGE POSITION ENGINEERED RESERVES WITH NEAR AND LONG TERM UPSIDE CONSISTENT AND DIVERSE INCOME STREAM ND

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Confidential – Not For Distribution 4

  • II. LAND OVERVIEW

Williston Basin Assets

WILLISTON BASIN ASSETS SUMMARY Producing Properties (Black trajectories on map) ▪ Whiting Petroleum Corporation ▪ ~1,351 net and ~46,768 gross acres ▪ 112 producing wells ▪ 3.1% WI / 2.6% NRI average ▪ Continental Resources ▪ ~508 net and ~14,198 gross acres ▪ 14 producing wells ▪ 4.9% WI / 4.1% NRI average ▪ Other operators ▪ ~102 net and ~5,888 gross acres ▪ 2 producing wells ▪ 4.1% WI / 3.4% NRI average DUC Wellbores (Solid red trajectories on map) ▪ 2 DUC wellbores ▪ 1 DUC with anticipated sales between July and September 2018 per Whiting completion program ▪ 1 confidential DUC operated by Thunderbird Permitted Wellbores (Dashed red trajectories on map) ▪ 12 permitted wellbores by Whiting Petroleum ▪ Anticipated sales dates specified in well files and are included in the VDR Additional PUD locations (not represented on map) ▪ 104 additional PUD locations identified ▪ New and infill drilling locations ▪ Assuming 5 wells per DSU

DUCS PERMITS

(1) Development plan by operator subject to change (2) Seller owns partial interest in highlighted sections. Refer to VDR for specific ownership information.

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Confidential – Not For Distribution 5

  • III. GEOLOGY OVERVIEW

Williston Basin | Three Forks Geology

STRATIGRAPHIC COLUMN ▪ The Williston Basin sedimentary deposition occurred, predominantly, during the Ordovician, Silurian and Devonian periods ▪ The Three Forks formation is of the upper Devonian period and is an unconventional carbonate play consisting of interbedded dolomites and shale ▪ Production from the Three Forks has proven feasibility of economic development under Seller’s acreage position THREE FORKS | ISOPACH MAPS

Source: Bakken/Three Forks Tight Oil Resource Play by Steve Sonnenberg

THREE FORKS | STRUCTURE MAP

Seller’s Position Seller’s Position Seller’s Position

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Confidential – Not For Distribution 6

  • IV. RESERVOIR ENGINEERING OVERVIEW

Reserves Summary

PRICING ASSUMPTIONS NET RESERVES SUMMARY NET RESERVES PROFILE NET PRODUCTION PROFILE

(1) Reserve equivalents calculated on energy equivalence of 6 Mcf/Bbl (2) Pricing differentials on an asset level average. Reserves database differentials assumed by Operator.

Oil 1,893 MBO 65% Gas 3.2 Bcf 19% NGL 477 MB 16%

Oil Gas Year ($/Bbl) ($/Mcf) 2018 $63.94 $2.79 2019 $59.06 $2.79 2020 $55.40 $2.75 2021 $53.10 $2.80 2022 $52.06 $2.85 2023 $51.83 $2.91 2024+ $52.11 $2.96 3/21/2018 Strip Price

PUD 2,432 MBOE 84% PDP 443 MBOE 15% PDNP 32 MBOE 1%

Oil Gas NGL ($/Bbl) ($/Mcf) (Frac of Oil) $0.08

  • $0.21

0.680 Differentials

Oil Gas NGL (MBO) (MMCF) (MB) Proved Reserves Proved Developed Producing 128 4.12 25,706.3 300.0 458.7 67.3 443.7 15% Proved Developed Non-Producing 2 0.05 1,767.8 26.6 30.2 0.3 31.9 1% Proved Undeveloped 116 4.03 112,042.7 1,566.8 2,733.6 409.5 2,432.0 84% Total 1P Reserves 246 8.20 139,516.7 1,893.4 3,222.5 477.1 2,907.6 % Reserves Gross No. Wells Net No. Wells Gross Reserves (MMBOE) Net Reserves Total (6:1) Net Equivalent (MBOE)

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Confidential – Not For Distribution 7

  • IV. RESERVOIR ENGINEERING OVERVIEW

Asset Production and Forecast

Historical Forecast

GROSS PRODUCTION PLOT | PDP AND UPSIDE

2 DUCS to be completed by Whiting Petroleum in Q3 2018 (1) and Thunderbird Resources in 2018 (1) ▪ Submitted plan of development to the NDIC with completion timeline (available in the VDR) 12 active permits to be drilled and completed by Whiting Petroleum based upon timeline submitted to NDIC in Gas Capture Plans (available in the VDR).

(1) Development plan by operator subject to change

104 additional new and infill drilling PUD locations identified and scheduled within SEC guidelines.

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Confidential – Not For Distribution 8

  • IV. RESERVOIR ENGINEERING

Three Forks / Pronghorn Formation Type Curve

THREE FORKS /PRONGHORN FORMATION OIL TYPE CURVE THREE FORKS / PRONGHORN SINGLE WELL ECONOMICS

Oil Gas NGL IP30 18.3 MBO 25.3 MMCF 3.2 MB Di 68% 53% 53% b-factor 1.30 1.30 1.30 EUR 594 MBO 1,228 MMCF 155 MB Economic EUR: 954 MBOE

D&C: $7MM Lateral Length: ~9,500’

  • Disc. Payout:

2.5 years ROR: 48%

(1) Calculated using strip pricing assumptions

THREE FORKS / PRONGHORN HORIZONTAL PUD LOCATIONS

DUCS PERMITS ADDITIONAL PUDS

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  • IV. RESERVOIR ENGINEERING

Whiting Petroleum Corporation | Enhanced Completion Designs Yielding Higher EURs

THREE FORKS /PRONGHORN FORMATION OIL TYPE CURVE

Source: Whiting Petroleum March 2018 Investor Presentation

WHITING | PRODUCTION RESULTS FROM ENHANCED COMPLETIONS

Seller’s approximate position

▪ Whiting Petroleum presents significant production results from enhanced completions ▪ Whiting has not yet implemented enhanced completion techniques on Seller’s position, providing significant additional upside in future development of the assets

WHITING ACREAGE | LOCATOR MAP

1 2 3 3 2 1

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  • IV. RESERVOIR ENGINEERING

Unquantified Upside | Three Forks Second and Third Bench Horizontal Potential

THREE FORKS FORMATION | ADDITIONAL UPSIDE WILLISTON BASIN | CROSS SECTION

▪ Multiple operators throughout the Williston Basin are testing and developing the second and third benches of the Three Forks formation ▪ Production results from Three Forks second and third bench wellbores provide support for economic development competitive with Three Forks first bench producing wellbores ▪ As the second and third bench become delineated by top operators, additional undeveloped locations may become available for further development of the Seller’s assets

Source: Continental Resources Investor Presentation

THREE FORKS STRATIGRAPHIC COLUMN

Seller’s approximate position Source: Continental Resources Investor Presentation

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  • V. ASSET HIGHLIGHTS AND SUMMARY

NON-OPERATED POSITION

UNDER

PLANNED DEVELOPMENT ▪ ~2,908 MBOE total net Proved Reserves (16% developed / 84% undeveloped) ▪ ~180 BOEPD net production (65% Oil / 19% Gas / 16% NGL) ▪ ~$178,000 monthly operating income (3-mo average) ▪ 2 DUC wells anticipated online in 2018 adding ~$37,000 monthly net operating income BLOCKED ACREAGE POSITION ▪ ~1,961 net and ~66,854 gross acres ▪ 128 producing wells (3.2% WI / 2.7% NRI average) ▪ 2 DUC wells under Whiting Petroleum (1) and Thunderbird Resources (1) ▪ 12 active permits with development timeline proposed by Whiting Petroleum with 104 additional PUD locations identified ENGINEERED RESERVES WITH NEAR AND LONG TERM UPSIDE ▪ ~444 MBOE PDP net Reserves ▪ ~32 MBOE DUC net Reserves with completions anticipated in 2018 ▪ ~2,432 MBOE PUD net Reserves ▪ Unquantified upside associated with horizontal Three Forks second and third bench formation targets CONSISTENT

AND DIVERSE

INCOME STREAM ▪ Predictable production and revenue stream from established production ▪ Operated predominantly by top Basin operator, Whiting Petroleum ▪ Primary Target: Three Forks / Pronghorn ▪ Significant drilling inventory with additional upside in NexGen D&C techniques

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Confidential – Not For Distribution 12

DISCLAIMER

The information contained herein has been prepared solely for informational purposes to assist with Recipient’s review of the Assets and to facilitate discussions relevant thereto. Seller nor Eagle River claim to present all information that may be necessary or desired to complete Recipient’s review. The materials have been prepared by Eagle River and are based on Eagle River’s assumptions and projections in addition to Seller’s, Third Parties’, and Governmental Agencies’ files, records, reports, data, assumptions, projections and opinions (the “Material”). Such Material is believed to be reliable and relevant; however, neither Seller nor Eagle River make any representations, express or implied, as to the completeness, accuracy, or adequacy of such Material presented

  • herein. It being understood by Recipient, that said Material is subject to change without notice. Recipient acknowledges that the information in the Material may also

include, but is not limited to, unqualified financial statements, economic and reserve reports and forecasts, commodity prices, oil and gas production data, lease

  • perating expenses, assumptions, projections, revenue statements, drilling and completion reports, title ownership records pertaining to leasehold, mineral ownership

reports and other information which may not be correct and which are subject to various risks. Recipient represents that Recipient is an experienced individual and/or entity who is engaged in the business of oil and gas operations, owns working interests, royalties, and/or mineral interests and understands the inherit risks associated with reviewing, valuing, purchasing, drilling, producing, and operating oil and gas assets. Recipient will conduct its own independent evaluation and due diligence and, as such, may wish to employ third party experts, consultants, and advisors to assist in its

  • review. Recipient will rely solely on its own independent evaluation and analysis for the purpose upon which it is to be utilized. Recipient agrees that neither the

Seller nor Eagle River shall be liable for any losses, damages, or claims resulting from the reliance on or use of such Material, from errors contained therein, or

  • missions therefrom.

This is not an offer to sell properties, assets, securities, and/or provide financing or any other form of a transaction. Recipient agrees that unless and until a final definitive written agreement regarding a transaction between Seller and Recipient has been executed and delivered, neither Seller nor Recipient will be under any legal obligation of any kind whatsoever with respect to a transaction by virtue of this Presentation. Recipient further acknowledges and agrees that Seller reserve the right, in their sole discretion, to reject any and all proposals of any nature made by Recipient and to terminate discussions and negotiations with Recipient at any time with or without notice of any kind. This Presentation is being provided pursuant to a Disclaimer which has been agreed to and executed by the Recipient.