CNX Announces 7% Increase in Proved Reserves to 8.43 Tcfe

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|Feb 11|magazine82 min read

PITTSBURGH, Feb. 10, 2020 /PRNewswire/ -- CNX Resources Corporation (NYSE: CNX) ("CNX" or "the company") announced today total proved reserves of 8.43 Tcfe, as of December 31, 2019, which is a 7% increase, compared to the previous year. CNX organically added 1,648 Bcfe of proved reserves through extensions and discoveries, which resulted in the company replacing over 300% of its 2019 net production of 539 Bcfe. These extensions and discoveries were a result of our continued development within the Marcellus and Utica Shale formations.

In 2019, drilling and completion costs incurred directly attributable to extensions and discoveries were $630 million. When divided by the extensions and discoveries of 1,648 Bcfe, this yields a drill bit F&D cost of $0.38 per Mcfe.

Future development costs for proved undeveloped reserves (PUDs) are estimated to be approximately $942 million, or $0.26 per Mcfe.

The following table shows the summary of changes in reserves:

Summary of Changes in Proved Reserves (Bcfe)

Balance at December 31, 2018

7,881

Extensions and discoveries                              

1,648

Performance Revisions                                         

709

Price Revisions and other                                         

(97)

Reclassification to unproved under SEC 5-year rule and Plan Changes

(1,176)

Production

(539)

Balance at December 31, 2019          

8,426

Note: The proved reserve estimate as of December 31, 2019, was prepared by CNX Resources and audited by Netherland, Sewell & Associates, Inc.

During the year, total net revisions were negative 564 Bcfe. The revisions included 709 Bcfe positive revisions due to improved well performance in both proved developed and proved undeveloped reserves, offset by 97 Bcfe negative pricing and other revisions primarily from decreasing natural gas prices compared to year-end 2018, 304 Bcfe of reductions due to the reclassification of PUD's through compliance with the SEC 5-Year rule, and 872 Bcfe negative revisions due to plans changes from our continued focus on portfolio optimization.

Proved developed and undeveloped reserves were 4,839 Bcfe (57%) and 3,587 Bcfe (43%), respectively, for 2019. PUDs at year-end 2019 represent 67% of the total wells the company expects to drill over the next five years. The low PUD to 5-year plan percentage implies meaningful future upside in both the Marcellus and Utica Shales in Pennsylvania and West Virginia.

During 2019, in the Marcellus Shale, CNX turned-in-line (TIL) 41 gross wells with an average completed lateral length of approximately 9,400 feet and expected ultimate recoveries (EURs) averaging 2.6 Bcfe per thousand feet of completed lateral. Completion optimization continues to drive EUR improvements in the Marcellus shale. This is accomplished through our utilization of new technology and refinements to our engineering approaches that allow for decreased cycle times and better recovery of our in-place resources. These improvements have allowed the company to book Marcellus Shale PUDs with average EURs of over 2.7 Bcfe per thousand feet of completed lateral, compared to 2.4 Bcfe per thousand feet booked in 2018.   

During 2019, in the Utica Shale, CNX turned-in-line (TIL) 10 gross wells with an average completed lateral length of approximately 6,400 feet. A majority of our proved undeveloped locations exist in our Ohio and CPA operating regions and their EURs are estimated to be 2.7 and 3.5 Bcfe per thousand feet of completed lateral.

As of December 31, 2019, CNX has total proved, probable, and possible reserves (also known as "3P reserves") of 10.3 Tcfe, which are comprised only of reserves expected to be developed in the company's five-year plan. There are an additional 113 Tcfe of recoverable resources in the Other Resource Potential that the company expects to develop beyond the five-year plan. The company continues drilling and completing Marcellus wells and testing dry Utica Shale potential in Pennsylvania and West Virginia and believes that these areas will provide additional opportunities for the company's proved reserves over time. The company's 3P reserves have been determined in accordance with the guidelines of the Society of Petroleum Engineers Petroleum Resources Management System.

The following table shows the breakdown of reserves, in Bcfe, from the company's current development and exploration plays:


Proved
Developed

Proved
Developed
Non-
Producing

Proved
Un-
Developed

Total
Proved

Probable

Possible

Total 3P

Other
Resource
Potential

Total
Reserve &
Resource

Marcellus
Shale

3,485

0

2,877

6.362

835

473

7,670

36,090

43,760

Coalbed
Methane

851

4

249

1,104

-

-

1,104

956

2,060

Utica

450

0

461

911

472

92

1,475

50,036

51,511

Other (1)

49

-

-

49

-

-

49

25,624

25,673

Total

4,835

4

3,587

8,426

1,307

565

10,298

112,706

123,004

(1) Other includes Conventional, Upper Devonian and Other Shale formations.

Definition: Total Reserve & Resource includes total 3P and other resource potential outside of 3P. 

The estimates of reserves and future revenue were prepared in accordance with the definitions and guidelines of the SEC Regulation S-X Rule 4.10(a).

The table below summarizes the Securities and Exchange Commission (SEC) pricing as of December 31, 2019:


SEC


Pricing (1)

Benchmark Pricing:


WTI Oil Price ($/Bbl)

$55.69

NYMEX Natural Gas Price ($/MMBtu)

$2.58

C2+ Natural Gas Liquids ($/Bbl)(2)

$19.10

Condensate ($/Bbl) (3)

$44.22

(1) The SEC rules require that the proved reserve calculations be based on the first day of the month unweighted arithmetic average prices over the preceding twelve months. 

(2) NGL Pricing is 34.3% of WTI, which includes regional market differentials.

(3) Condensate Pricing is 79.4% of WTI, which includes regional market differentials.

Based on these prices adjusted for quality, hedges, transportation costs, and basis differentials ($2.24 per Mcf, $19.10 per barrel of natural gas liquids, $44.22 per barrel of condensate and $50.69 per barrel of crude oil, respectively), the pre-tax discounted (10%) present value ("PV-10") of the company's proved reserves was $4.18 billion for 2019, compared to $6.17 billion at year-end 2018.

Standardized Measure of Discounted Future Net Cash Flows
The following information was prepared in accordance with the provisions of the Financial Accounting Standards Board's Accounting Standards Update No. 2010-03, "Extractive Activities-Oil and Gas (Topic 932)." This topic requires the standardized measure of discounted future net cash flows to be based on the average, first-day-of-the-month price for the year ended December 31, 2019. Because prices used in the calculation are average prices for that year, the standardized measure could vary significantly from year-to-year based on the market conditions that occurred.

The projections should not be viewed as realistic estimates of future cash flows, nor should the "standardized measure" be interpreted as representing current value to CNX. Material revisions to estimates of proved reserves may occur in the future; development and production of the reserves may not occur in the periods assumed; actual prices realized are expected to vary significantly from those used and actual costs may vary. CNX's investment and operating decisions are not based on the information presented, but on a wide range of reserve estimates that include probable as well as proved reserves and on different price and cost assumptions.

The standardized measure is intended to provide a better means for comparing the value of CNX's proved reserves at a given time with those of other gas producing companies than is provided by a comparison of raw proved reserve quantities.

Reconciliation of PV-10 to Standardized Measure 





December 31,

(Dollars in millions)


2019


2018


2017

Future cash inflows


$      19,490


$      26,610


$      19,262

Future production costs


(7,903)


(7,730)


(7,234)

Future development costs (including abandonments)


(1,121)


(1,600)


(1,711)

Future net cash flows (pre-tax)


10,466


17,280


10,317

10% discount factor


(6,290)


(11,108)


(6,177)

PV-10 (Non-GAAP measure) (1)


4,176


6,172


4,140

Undiscounted income taxes


(2,721)


(4,147)


(2,476)

10% discount factor


1,615


2,630


1,467

Discounted income taxes


(1,106)


(1,516)


(1,009)

Standardized GAAP measure


$        3,070


$        4,655


$        3,131

(1)

We calculate our present value at 10% (PV-10) in accordance with the following table. Management believes that the presentation of the non-Generally Accepted Accounting Principle (GAAP) financial measure of PV-10 provides useful information to investors because it is widely used by professional analysts and sophisticated investors in evaluating oil and gas companies. Because many factors that are unique to each individual company impact the amount of future income taxes estimated to be paid, the use of a pre-tax measure is valuable when comparing companies based on reserves. PV-10 is not a measure of the financial or operating performance under GAAP. PV-10 should not be considered as an alternative to the standardized measure as defined under GAAP. We have included a reconciliation of the most directly comparable GAAP measure-after-tax discounted future net cash flows.

About CNX Resources
CNX Resources Corporation is one of the largest independent natural gas exploration, development and production companies, with operations centered in the major shale formations of the Appalachian basin. The company deploys an organic growth strategy focused on responsibly developing its resource base. As of December 31, 2019, CNX had 8.43 trillion cubic feet equivalent of proved natural gas, natural gas liquids, condensate and oil reserves. The company is a member of the Standard & Poor's Midcap 400 Index. Additional information may be found at www.cnx.com.

Cautionary Statements

We are including the following cautionary statement in this press release to make applicable and take advantage of the safe harbor provisions of the Private Securities Litigation Reform Act of 1995 for any forward-looking statements made by, or on behalf of us. With the exception of historical matters, the matters discussed in this press release are forward-looking statements (as defined in 21E of the Securities Exchange Act of 1934 (the "Exchange Act")) that involve risks and uncertainties that could cause actual results to differ materially from projected results. Accordingly, investors should not place undue reliance on forward-looking statements as a prediction of actual results. These forward-looking statements may include projections and estimates concerning the timing and success of specific projects and our future production, revenues, income and capital spending. When we use the words "believe," "intend," "expect," "may," "should," "anticipate," "could," "estimate," "plan," "predict," "project," "will," or their negatives, or other similar expressions, the statements which include those words are usually forward-looking statements. When we describe a strategy that involves risks or uncertainties, we are making forward-looking statements. The forward-looking statements in this press release speak only as of the date of this press release; we disclaim any obligation to update these statements. We have based these forward-looking statements on our current expectations and assumptions about future events. While our management considers these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks, contingencies and uncertainties, most of which are difficult to predict and many of which are beyond our control. These risks, contingencies and uncertainties relate to, among other matters, the following: prices for natural gas and natural gas liquids are volatile and can fluctuate widely based upon a number of factors beyond our control including oversupply relative to the demand for our products, weather and the price and availability of alternative fuels; our dependence on gathering, processing and transportation facilities and other midstream facilities owned by CNX Midstream Partners LP (CNXM) and others; uncertainties in estimating our economically recoverable natural gas reserves, and inaccuracies in our estimates; the high-risk nature of drilling, developing and operating natural gas wells; our identified drilling locations are scheduled out over multiple years, making them susceptible to uncertainties that could materially alter the occurrence or timing of their development or drilling; challenges associated with strategic determinations, including the allocation of capital and other resources to strategic opportunities; the substantial capital expenditures required for our development and exploration projects, as well as CNXM's midstream system development; the impact of potential, as well as any adopted, environmental regulations, including those relating to greenhouse gas emissions; environmental regulations can increase costs and introduce uncertainty that could adversely impact the market for natural gas with potential short and long-term liabilities; decreases in the availability of, or increases in the price of, required personnel, services, equipment, parts and raw materials in sufficient quantities or at reasonable costs to support our operations; if natural gas prices decrease or drilling efforts are unsuccessful, we may be required to record write-downs of our proved natural gas properties, and changes in assumptions impacting management's estimates of future financial results as well as other assumptions such as movement in our stock price, weighted-average cost of capital, terminal growth rates and industry multiples, could cause goodwill and other intangible assets we hold to become impaired and result in material non-cash charges to earnings; a loss of our competitive position because of the competitive nature of the natural gas industry, consolidation within the industry or overcapacity in the industry adversely affecting our ability to sell our products and midstream services; deterioration in the economic conditions in any of the industries in which our customers operate, a domestic or worldwide financial downturn, or negative credit market conditions; hedging activities may prevent us from benefiting from price increases and may expose us to other risks; existing and future government laws, regulations and other legal requirements and judicial decisions that govern our business may increase our costs of doing business and may restrict our operations; significant costs and liabilities may be incurred as a result of pipeline operations and related increase in the regulation of gas gathering pipelines; our ability to find adequate water sources for our use in shale gas drilling and production operations, or our ability to dispose of, transport or recycle water used or removed in connection with our gas operations at a reasonable cost and within applicable environmental rules; failure to successfully estimate the rate of decline or existing reserves or to find or acquire economically recoverable natural gas reserves to replace our current natural gas reserves; risks associated with our current long-term debt obligations; a decrease in our borrowing base, which could decrease for a variety of reasons including lower natural gas prices, declines in natural gas proved reserves, asset sales and lending requirements or regulations; changes in federal or state income tax laws; cyber-incidents could have a material adverse effect on our business, financial condition or results of operations; construction of new gathering, compression, dehydration, treating or other midstream assets by CNXM may not result in revenue increases and may be subject to regulatory, environmental, political, legal and economic risks; our success depends on key members of our management and our ability to attract and retain experienced technical and other professional personnel; terrorist activities could materially and adversely affect our business and results of operations; we may operate a portion of our business with one or more joint venture partners or in circumstances where we are not the operator, which may restrict our operational and corporate flexibility and we may not realize the benefits we expect to realize from a joint venture; acquisitions and divestitures we anticipate may not occur or produce anticipated benefits; the outcomes of various legal proceedings, including those which are more fully described in our reports filed under the Exchange Act; there is no guarantee that we will continue to repurchase shares of our common stock under our current or any future share repurchase program at levels undertaken previously or at all; negative public perception regarding our industry could have an adverse effect on our operations; CONSOL Energy may not be able to satisfy its indemnification obligations in the future and such indemnities may not be sufficient to hold us harmless from the full amount of liabilities for which CONSOL Energy will be allocated responsibility.  Additional factors are described in detail under the captions "Forward Looking Statements" and "Risk Factors" in our annual report on Form 10-K for the year ended December 31, 2019 filed with the Securities and Exchange Commission, as supplemented by our quarterly reports on Form 10-Q.

 

 

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SOURCE CNX Resources Corporation