Form 8-K REX ENERGY CORP For: Nov 08
Tweet
Share
E-mail
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 8-K
CURRENT REPORT
PURSUANT TO SECTION 13 OR 15(D) OF THE
SECURITIES EXCHANGE ACT OF 1934
Date of Report (Date of earliest event reported): November 8, 2016
Rex Energy Corporation
(Exact name of registrant as specified in its charter)
| Delaware | 001-33610 | 20-8814402 | ||
| (State or other jurisdiction of incorporation) |
(Commission File Number) |
(IRS Employer Identification No.) |
366 Walker Drive
State College, Pennsylvania 16801
(Address of Principal Executive Office and Zip Code)
(814) 278-7267
(Registrant’s telephone number, including area code)
Not Applicable
(Former name or former address, if changed since last report)
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligations of the registrant under any of the following provisions:
| ☐ | Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425) |
| ☐ | Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12) |
| ☐ | Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b)) |
| ☐ | Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c)) |
Item 2.02 Results of Operations and Financial Condition.
On November 8, 2016, Rex Energy Corporation (“Rex Energy”) issued a press release announcing its financial results for third quarter 2016. A copy of the press release is attached as Exhibit 99.1 to this Current Report on Form 8-K and incorporated herein by reference.
In accordance with General Instruction B.2 of Form 8-K, the information under this heading, including the related Exhibit 99.1, shall not be deemed “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, or otherwise subject to the liabilities of that section, nor shall it be deemed incorporated by reference in any filing under the Securities Act of 1933, as amended, except as shall be expressly set forth in such a filing.
Item 7.01 Regulation FD Disclosure.
On November 8, 2016, Rex Energy will make available on its website an updated “Rex Energy Corporate Presentation,” which includes updated information relating to basis differentials, among other things. The presentation can be accessed by going to www.rexenergy.com, selecting the “Investor Relations” tab, and then selecting the “Events & Presentations” tab. The presentation will be available on the company’s website until the next regular update.
In accordance with General Instruction B.2 of Form 8-K, the information under this heading shall not be deemed “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, or otherwise subject to the liabilities of that section, nor shall it be deemed incorporated by reference in any filing under the Securities Act of 1933, as amended, except as shall be expressly set forth in such a filing.
Item 9.01 Financial Statements and Exhibits.
(d) Exhibits.
| Exhibit |
Exhibit Title | |
| 99.1 | Press Release of Rex Energy Corporation dated November 8, 2016. | |
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.
| REX ENERGY CORPORATION | ||||||
| Date: November 8, 2016 | By: | /s/ Jennifer L. McDonough | ||||
| Name: Jennifer L. McDonough | ||||||
| Title: Sr. Vice President, General Counsel and Secretary | ||||||
EXHIBIT INDEX
| Exhibit |
Exhibit Title | |
| 99.1 | Press Release of Rex Energy Corporation dated November 8, 2016. | |
Exhibit 99.1
Rex Energy Reports Third Quarter Operational and Financial Results
| • | In Moraine East, placed three Marcellus wells on the Fleeger II pad into sales; 24 hour sales rate of 10.4 MMcfe/d; 56% liquids |
| • | Gulf Coast transport online November 1, 2016; moving 130,000 Mmbtu per day of natural gas from Butler Operated Area to Gulf Coast and Midwest premium markets |
| • | Production from continuing operations of 197.8 MMcfe/d, an 8% increase year-over-year |
| • | Reaffirmed borrowing base of $190 million; next redetermination scheduled for Spring 2017 |
STATE COLLEGE, PA., November 8, 2016 (GLOBE NEWSWIRE) – Rex Energy Corporation (Nasdaq: REXX) today announced its third quarter 2016 operational and financial results.
Third Quarter Financial Results
Unless otherwise noted, results of continuing operations are presented excluding the results of the company’s Illinois Basin assets, which have been classified as discontinued operations, for all periods presented.
Operating revenue from continuing operations for the three and nine months ended September 30, 2016 was $34.0 million and $91.0 million, respectively, which represents an increase of 15% and a decrease of 18% over the same periods in 2015. Commodity revenues, including settlements from derivatives, for the three and nine months ended September 30, 2016 were $36.3 million and $123.7 million, a decrease of 19% and 18% for the same periods in 2015, respectively. Commodity revenues from condensate and natural gas liquids (NGLs), including settlements from derivatives, represented 50% of total commodity revenues for the three months ended September 30, 2016.
Lease operating expense (LOE) from continuing operations was $26.3 million, or $1.45 per Mcfe for the quarter. For the nine months ended September 30, 2016, LOE was approximately $76.0 million, or $1.42 per Mcfe. General and administrative expenses from continuing operations were $5.1 million for the third quarter of 2016, a 4% increase on a per unit basis as compared to the same period in 2015. Cash general and administrative expenses from continuing operations, a non-GAAP measure, were $4.1 million for the third quarter of 2016, an 18% decrease on a per unit basis as compared to the same period in 2015. For the nine months ended September 30, 2016, G&A expenses from continuing operations were $15.2 million, a 30% decrease on a per unit basis as compared to the same period in 2015. Cash G&A expenses from continuing operations were $13.2 million, a 19% decrease on a per unit basis as compared to the same period in 2015.
Net income attributable to common shareholders for the three months ended September 30, 2016 was $4.8 million, or $0.05 per basic share. Net loss attributable to common shareholders for the nine months ended September 30, 2016 was $41.4 million, or $0.57 per basic share. Adjusted net loss, a non-GAAP measure, for the three months ended September 30, 2016 was $12.3 million, or $0.14 per share. Adjusted net loss for the nine months ended September 30, 2016 was $29.7 million, or $0.41 per share.
EBITDAX from continuing operations, a non-GAAP measure, was $4.5 million for the third quarter of 2016 and $32.0 million for the nine months ended September 30, 2016.
Reconciliations of adjusted net income to GAAP net income, EBITDAX to GAAP net income and G&A to cash G&A for the three months and nine months ended September 30, 2016, as well as a discussion of the uses of each measure, are presented in the appendix of this release.
Production Results and Price Realizations
Third quarter 2016 production volumes from continuing operations were 197.8 MMcfe/d, an increase of 8% over the third quarter of 2015, consisting of 118.8 MMcf/d of natural gas and 13.2 Mboe/d of condensate and NGLs (including 6.6 Mboe/d of ethane). Condensate and NGLs (including ethane) accounted for 40% of net production for the third quarter of 2016.
Including the effects of cash-settled derivatives, realized prices for the three months ended September 30, 2016 were $1.65 per Mcf for natural gas, $39.70 per barrel for condensate, $18.15 per barrel for NGLs (C3+) and $8.15 per barrel for ethane. Before the effects of hedging, realized prices for the three months ended September 30, 2016 were $1.54 per Mcf for natural gas, $38.82 per barrel for condensate, $16.48 per barrel for NGLs (C3+) and $7.99 per barrel for ethane. Third quarter 2016 price realizations were negatively impacted by the early termination of hedges during the second quarter of 2016.
Including the effects of cash-settled derivatives, realized prices for the nine months ended September 30, 2016 were $2.17 per Mcf for natural gas, $43.18 per barrel for condensate, $18.78 per barrel for NGLs (C3+) and $7.43 per barrel for ethane. Before the effects of hedging, realized prices for the nine months ended September 30, 2016 were $1.44 per Mcf for natural gas, $34.72 per barrel for condensate, $14.74 per barrel for NGLs (C3+) and $7.28 per barrel for ethane.
Third Quarter 2016 Capital Investments
For the third quarter of 2016, net operational capital investments were approximately $10.9 million. The company expects to be reimbursed by joint venture partners for approximately $11.8 million of previously incurred costs that were not billed until the fourth quarter. These capital investments funded the drilling of four gross (1.4 net) wells, fracture stimulation of three gross (1.8 net) wells, placing four gross (2.1 net) wells into sales and other projects related to drilling and completing wells in the Appalachian Basin.
Third quarter investments for leasing and property acquisitions were $0.4 million and capitalized interest was $0.3 million.
Operational Update
Appalachian Basin – Legacy Butler Operated Area
During the third quarter of 2016, the company placed into sales the two-well Geyer pad. The Geyer wells were drilled to an average lateral length of approximately 4,200 feet and were completed in an average of 24 stages. The wells produced at an average 5-day sales rate per well, assuming full ethane recovery, of 6.1 MMcfe/d, consisting of 3.8 MMcf/d of gas and 387 bbls/d of NGLs.
Appalachian Basin – Moraine East Area
In the Moraine East Area, Rex Energy drilled one gross (0.4 net) well during the third quarter of 2016. In addition, the company had six gross (2.1 net) wells awaiting completion at the end of the third quarter.
During the third quarter of 2016, the company placed the four-well Fleeger II pad into sales, consisting of three Marcellus wells and one Upper Devonian well. The Fleeger II wells were drilled to an average lateral length of approximately 7,760 feet and completed in an average of 46 stages with average sand concentrations of 2,444 pounds per foot. The three Marcellus wells produced at an average 24-hour sales rate per well, assuming full ethane recovery, of 10.4 MMcfe/d, consisting of 4.3 MMcf/d of natural gas, 851 bbls/d of NGLs and 154 bbls/d of condensate. The Upper Devonian Burkett well, the Fleeger II 3H, produced at a 24-hour sales rate of 7.0 MMcfe/d, consisting of 2.9 MMcf/d of natural gas, 557 bbls/d of NGLs and 133 bbls/d of condensate. The Fleeger II 3H has not fully dewatered and is continuing to improve as it cleans up.
The company recently completed the two-well Klever pad, which was drilled to an average lateral length of approximately 7,460 feet. The pad is expected to be placed into sales during the fourth quarter of 2016. The company also expects to complete the four-well Baird pad in the fourth quarter of 2016 and place the pad into sales in January 2017. Horizontal drilling has started on the six-well Shields pad, which is expected to have an average lateral length of approximately 7,750 feet. The Shields pad is expected to be placed into sales in the second quarter of 2017.
Appalachian Basin – Warrior North Area – Carroll County, Ohio
In the Warrior North Area, Rex Energy drilled 3.5 gross (1.2 net) wells during the third quarter of 2016. The company is currently completing the four-well Vaughn pad, which was drilled to an average lateral length of approximately 7,200 feet. The Vaughn pad is expected to be placed into sales in December 2016.
Appalachian Basin – Year to Date HBP / Production
Rex Energy continues to focus its development efforts in its core areas of the Appalachian Basin. The table below provides the company’s projections for assets held by production to date and by year-end 2016, with associated potential future drilling locations and exit rate estimates.
| Moraine East | Warrior North | |||||
| YE 2016E | YTD | YE 2016E | ||||
| Total Acreage HBP |
22,000 | 6,700 | 11,800 | |||
| % Acreage HBP |
61% | 56% | 98% | |||
| Gross / Net Locations HBP |
217 / 184 | 40 / 32 | 54 / 46 | |||
| % Gross / Net Locations HBP |
56% / 56% | 68% / 63% | 92% / 90% | |||
| Gross Exit Rate Production |
69.1 MMcfe/d | — | 67.6 MMcfe/d | |||
Appalachian Basin – Marketing Update
On November 1, 2016, Rex Energy began transporting 130 MMbtu/d of natural gas volumes from its Butler Operated Area to the Gulf Coast and Midwest markets. The commencement of this transportation allows the company to access premium markets in the Midwest and the Gulf Coast, including the future
Freeport LNG export facilities, where the company will receive Henry Hub pricing at a minimal discount. Rex Energy expects to transport approximately 50% of its natural gas volumes to these markets. With Gulf Coast transportation in place for full-year 2017, the company expects its overall basis differential to improve by approximately 50% over its full-year 2016 basis differential.
Earlier this year, Rex Energy began selling ethane from the Butler Operated and Warrior North Areas on Mariner East out of the Marcus Hook facility. The access to international markets has resulted in the company receiving a premium to Mont. Belvieu pricing.
During the second half of 2016, the company renegotiated its condensate pricing agreements, resulting in over $5.00/bbl incremental value in condensate pricing.
Liquidity Update
During the third quarter, Rex Energy completed the sale of its Illinois Basin assets for approximately $40 million and the company’s bank group reaffirmed the $190 million borrowing base under the its senior secured credit facility.
Projections for Operations; Fourth Quarter and Full Year 2016 Guidance
The following table summarizes Rex Energy’s operational activities for full-year 2016and projected status at year-end in each of its core operating areas:
| Legacy Butler |
Moraine East |
Warrior North | ||||
| Wells Drilled Gross / Net |
2.0 / 1.4 | 10.0 / 3.5 | 7.0 / 2.5 | |||
| Wells Completed Gross / Net |
2.0 / 1.4 | 6.0 / 2.7 | 10.0 / 4.2 | |||
| Wells Placed Into Sales Gross / Net |
2.0 / 1.4 | 18.0 / 8.7 | 13.0 / 5.2 | |||
| Commenced Pad Operations (@ YE) |
— | 3.0 pads | — |
In addition, the company is providing its guidance for the fourth quarter of 2016 and full-year 2016 ($ in millions):
| 4Q2016 |
Full Year 2016 | |||
| Production |
194.0 – 200.0 MMcfe/d | 7% YoY Growth | ||
| Lease Operating Expense |
$28.0 - $31.0 million | — | ||
| Cash G&A |
$3.7 - $4.7 million | — | ||
| Net Operational Capital Expenditures(1) |
— | $35.5 million |
| (1) | Land acquisition expense and capitalized interest are not included in the operational capital expenditures budget |
Conference Call Information
Management will host a live conference call and webcast on Wednesday, November 9, 2016 at 10:00 a.m. Eastern to review third quarter 2016 financial results and operational highlights. The telephone number to access the conference call is (866) 437-1772.
About Rex Energy Corporation
Headquartered in State College, Pennsylvania, Rex Energy is an independent oil and gas exploration and production company with its core operations in the Appalachian Basin. The company’s strategy is to pursue its higher potential exploration drilling prospects while acquiring oil and natural gas properties complementary to its portfolio.
Forward-Looking Statements
Except for historical information, statements made in this release, including those relating to the timing and nature of development plans; drilling and completion schedules; anticipated fracture stimulation activities; expected dates for placement of wells into sales; projections of operations at year-end 2016; and our financial guidance for fourth quarter and full year 2016 are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Forward-looking statements may contain words such as “expected”, “expects”, “scheduled”, “planned”, “plans”, “anticipates” or similar words, and are based on management’s experience and perception of historical trends, current conditions, and anticipated future developments, as well as other factors believed to be appropriate. We believe these statements and the assumptions and estimates contained in this release are reasonable based on information that is currently available to us. However, management’s assumptions and the company’s future performance are subject to a wide range of business risks and uncertainties, both known and unknown, and we cannot assure that the company can or will meet the goals, expectations, and projections included in this release. Any number of factors could cause our actual results to be materially different from those expressed or implied in our forward looking statements, including (without limitation):
| • | volatility in oil, NGL, and natural gas pricing; |
| • | domestic and global demand for oil, NGLs and natural gas; |
| • | economic conditions in the United States and globally; |
| • | the adequacy and availability of capital resources, credit, and liquidity including, but not limited to, access to additional borrowing capacity; |
| • | conditions in the domestic and global capital and credit markets and their effect on us; |
| • | new or changing government regulations, including those relating to environmental matters, permitting, or other aspects of our operations; |
| • | the geologic quality of the company’s properties with regard to, among other things, the existence of hydrocarbons in economic quantities; |
| • | uncertainties inherent in the estimates of our oil and natural gas reserves; |
| • | our ability to increase oil and natural gas production and income through exploration and development; |
| • | drilling and operating risks; |
| • | the success of our drilling techniques in both conventional and unconventional reservoirs; |
| • | the success of the secondary and tertiary recovery methods we utilize or plan to employ in the future; |
| • | the number of potential well locations to be drilled, the cost to drill them, and the time frame within which they will be drilled; |
| • | the ability of contractors to timely and adequately perform their drilling, construction, well stimulation, completion and production services; |
| • | the availability of equipment, such as drilling rigs, and infrastructure, such as transportation, pipelines, processing and midstream services; |
| • | the effects of adverse weather or other natural disasters on our operations; |
| • | competition in the oil and gas industry in general, and specifically in our areas of operations; |
| • | changes in our drilling plans and related budgets; |
| • | the success of prospect development and property acquisition; |
| • | the success of our business and financial strategies, and hedging strategies; and |
| • | uncertainties related to the legal and regulatory environment for our industry, and our own legal proceedings and their outcome. |
We undertake no obligation to publicly update or revise any forward-looking statements. Further information on the company’s risks and uncertainties is available in our filings with the Securities and Exchange Commission and we strongly encourage investors to review those filings.
* * * * *
For more information contact:
Investor Relations
(814) 278-7130
REX ENERGY CORPORATION
CONSOLIDATED BALANCE SHEETS
($ in Thousands, Except Share and Per Share Data)
| September 30, 2016 (Unaudited) |
December 31, 2015 | |||||||
| ASSETS |
||||||||
| Current Assets |
||||||||
| Cash and Cash Equivalents |
$ | 2,524 | $ | 1,091 | ||||
| Accounts Receivable |
21,655 | 17,274 | ||||||
| Taxes Receivable |
211 | 18 | ||||||
| Short-Term Derivative Instruments |
5,461 | 34,260 | ||||||
| Inventory, Prepaid Expenses and Other |
1,079 | 3,059 | ||||||
| Assets Held for Sale |
— | 60,451 | ||||||
|
|
|
|
|
|||||
| Total Current Assets |
30,930 | 116,153 | ||||||
| Property and Equipment (Successful Efforts Method) |
||||||||
| Evaluated Oil and Gas Properties |
1,020,993 | 943,092 | ||||||
| Unevaluated Oil and Gas Properties |
223,791 | 262,992 | ||||||
| Other Property and Equipment |
21,449 | 20,363 | ||||||
| Wells and Facilities in Progress |
66,614 | 141,100 | ||||||
| Pipelines |
15,186 | 14,024 | ||||||
|
|
|
|
|
|||||
| Total Property and Equipment |
1,348,033 | 1,381,571 | ||||||
| Less: Accumulated Depreciation , Depletion and Amortization |
(459,549 | ) | (437,828 | ) | ||||
|
|
|
|
|
|||||
| Net Property and Equipment |
888,484 | 943,743 | ||||||
| Other Assets |
2,492 | 2,501 | ||||||
| Long-Term Derivative Instruments |
3,367 | 9,534 | ||||||
|
|
|
|
|
|||||
| Total Assets |
$ | 925,273 | $ | 1,071,931 | ||||
| LIABILITIES AND EQUITY |
||||||||
| Current Liabilities |
||||||||
| Accounts Payable |
$ | 29,464 | $ | 36,785 | ||||
| Current Maturities of Long-Term Debt |
201 | 402 | ||||||
| Accrued Liabilities |
29,619 | 40,608 | ||||||
| Short-Term Derivative Instruments |
9,294 | 2,486 | ||||||
| Liabilities Related to Assets Held for Sale |
631 | 36,320 | ||||||
|
|
|
|
|
|||||
| Total Current Liabilities |
69,209 | 116,601 | ||||||
| Long-Term Derivative Instruments |
3,354 | 5,556 | ||||||
| Senior Secured Line of Credit and Long-Term Debt, Net of Issuance Costs |
126,061 | 109,386 | ||||||
| Senior Notes, Net of Issuance Costs and Deferred Gain on Debt Exchanges |
633,322 | 663,089 | ||||||
| Premium on Senior Notes, Net |
134 | 2,344 | ||||||
| Other Deposits and Liabilities |
9,617 | 3,156 | ||||||
| Future Abandonment Cost |
7,438 | 11,568 | ||||||
|
|
|
|
|
|||||
| Total Liabilities |
$ | 849,135 | $ | 911,700 | ||||
| Stockholder Equity |
||||||||
| Preferred Stock, $.001 par value per share, 100,000 shares authorized and 4,087 issued and outstanding on September 30, 2016 and 16,100 shares issued and outstanding on December 31, 2015 |
$ | 1 | $ | 1 | ||||
| Common Stock, $.001 par value per share, 200,000,000 shares authorized and 95,886,983 shares issued and outstanding on September 30, 2016 and 55,741,229 shares issued and outstanding on December 31, 2015 |
94 | 54 | ||||||
| Additional Paid-In Capital |
649,103 | 623,863 | ||||||
| Accumulated Deficit |
(573,060 | ) | (463,687 | ) | ||||
|
|
|
|
|
|||||
| Total Stockholders’ Equity |
76,138 | 160,231 | ||||||
|
|
|
|
|
|||||
| Total Liabilities and Owners’ Equity |
$ | 925,273 | $ | 1,071,931 | ||||
|
|
|
|
|
|||||
REX ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited, in Thousands, Except per Share Data)
| For the Three Months Ended September 30, |
For the Nine Months Ended September 30, |
|||||||||||||||
| 2016 | 2015 | 2016 | 2015 | |||||||||||||
| OPERATING REVENUE |
||||||||||||||||
| Natural Gas, Condensate and NGL Sales |
$ | 34,034 | $ | 29,648 | $ | 90,978 | $ | 111,344 | ||||||||
| Other Revenue |
5 | 8 | 12 | 30 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| TOTAL OPERATING REVENUE |
34,039 | 29,656 | 90,990 | 111,374 | ||||||||||||
| OPERATING EXPENSES |
||||||||||||||||
| Production and Lease Operating Expense |
26,333 | 24,259 | 76,005 | 71,646 | ||||||||||||
| General and Administrative Expense |
5,116 | 4,507 | 15,237 | 20,253 | ||||||||||||
| (Gain) Loss on Disposal of Assets |
10 | (224 | ) | (4,285 | ) | (533 | ) | |||||||||
| Impairment Expense |
9,563 | 85,193 | 45,344 | 209,880 | ||||||||||||
| Exploration Expense |
216 | 580 | 1,954 | 1,774 | ||||||||||||
| Depreciation, Depletion, Amortization and Accretion |
15,109 | 20,832 | 46,371 | 67,369 | ||||||||||||
| Other Operating Expense |
9,899 | 190 | 10,930 | 5,328 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| TOTAL OPERATING EXPENSES |
66,246 | 135,337 | 191,556 | 375,717 | ||||||||||||
| LOSS FROM OPERATIONS |
(32,207 | ) | (105,681 | ) | (100,566 | ) | (264,343 | ) | ||||||||
| OTHER EXPENSE |
||||||||||||||||
| Interest Expense |
(9,646 | ) | (11,884 | ) | (34,115 | ) | (36,077 | ) | ||||||||
| Gain (Loss) on Derivatives, Net |
16,866 | 28,649 | (8,254 | ) | 45,487 | |||||||||||
| Other Income |
16 | 25 | 28 | 118 | ||||||||||||
| Debt Exchange Expense |
(35 | ) | — | (9,048 | ) | — | ||||||||||
| Gain on Extinguishment of Debt |
423 | — | 24,130 | — | ||||||||||||
| Loss on Equity Method Investments |
— | — | — | (411 | ) | |||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| TOTAL OTHER INCOME (EXPENSE) |
7,624 | 16,790 | (27,259 | ) | 9,117 | |||||||||||
| LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX |
(24,583 | ) | (88,891 | ) | (127,825 | ) | (255,226 | ) | ||||||||
| Income Tax Benefit |
8,106 | — | 5,785 | — | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| NET LOSS FROM CONTINUING OPERATIONS |
(16,477 | ) | (88,891 | ) | (122,040 | ) | (255,226 | ) | ||||||||
| Income (Loss) From Discontinued Operations, Net of Income Taxes |
21,892 | (5,785 | ) | 12,719 | (7,770 | ) | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| NET INCOME (LOSS) |
5,415 | (94,676 | ) | (109,321 | ) | (262,996 | ) | |||||||||
| Net Income (Loss) Attributable to Noncontrolling Interests |
— | (1 | ) | — | 2,245 | |||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY |
5,415 | (94,675 | ) | (109,321 | ) | (265,241 | ) | |||||||||
| Preferred Stock Dividends |
(613 | ) | (2,415 | ) | (4,441 | ) | (7,245 | ) | ||||||||
| Effect of Preferred Stock Conversion |
— | — | 72,316 | — | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS |
$ | 4,802 | $ | (97,090 | ) | $ | (41,446 | ) | $ | (272,486 | ) | |||||
|
|
|
|
|
|
|
|
|
|||||||||
| Earnings per common share: |
||||||||||||||||
| Basic – Net Loss From Continuing Operations Attributable to Rex Energy Common Shareholders |
$ | (0.19 | ) | $ | (1.69 | ) | $ | (0.74 | ) | $ | (4.88 | ) | ||||
| Basic – Net Income (Loss) From Discontinued Operations Attributable to Rex Energy Common Shareholders |
0.24 | (0.11 | ) | 0.17 | (0.19 | ) | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Basic – Net Income (Loss) Attributable to Rex Energy Common Shareholders |
$ | 0.05 | $ | (1.80 | ) | $ | (0.57 | ) | $ | (5.07 | ) | |||||
| Basic – Weighted Average Shares of Common Stock Outstanding |
90,803 | 53,936 | 73,098 | 53,748 | ||||||||||||
| Diluted – Net Loss From Continuing Operations Attributable to Rex Energy Common Shareholders |
$ | (0.19 | ) | $ | (1.69 | ) | $ | (0.74 | ) | $ | (4.88 | ) | ||||
| Diluted – Net Income (Loss) From Discontinued Operations Attributable to Rex Energy Common Shareholders |
0.24 | (0.11 | ) | 0.17 | (0.19 | ) | ||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Diluted – Net Income (Loss) Attributable to Rex Energy Common Shareholders |
$ | 0.05 | $ | (1.80 | ) | $ | (0.57 | ) | $ | (5.07 | ) | |||||
| Diluted – Weighted Average Shares of Common Stock Outstanding |
90,803 | 53,936 | 73,098 | 53,748 | ||||||||||||
REX ENERGY CORPORATION
CONSOLIDATED OPERATIONAL HIGHLIGHTS
UNAUDITED
| Three Months Ending September 30, |
Nine Months Ending September 30, |
|||||||||||||||
| 2016 | 2015 | 2016 | 2015 | |||||||||||||
| Oil, Natural Gas, NGL and Ethane sales (in thousands): |
||||||||||||||||
| Natural gas sales |
$ | 16,871 | $ | 18,684 | $ | 48,431 | $ | 68,057 | ||||||||
| Condensate sales |
4,096 | 2,837 | 8,998 | 12,257 | ||||||||||||
| Natural gas liquids (C3+) sales |
8,211 | 5,069 | 22,053 | 24,872 | ||||||||||||
| Ethane sales |
4,855 | 3,058 | 11,495 | 6,158 | ||||||||||||
| Cash-settled derivatives: |
||||||||||||||||
| Natural gas |
1,200 | 8,911 | 24,280 | 23,250 | ||||||||||||
| Condensate |
93 | 2,694 | 2,191 | 8,807 | ||||||||||||
| Natural gas liquids (C3+) |
830 | 3,446 | 6,040 | 7,111 | ||||||||||||
| Ethane |
97 | — | 241 | — | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Total oil, gas, NGL and Ethane sales including cash settled derivatives |
$ | 36,253 | $ | 44,699 | $ | 123,729 | $ | 150,512 | ||||||||
| Production during the period: |
||||||||||||||||
| Natural gas (Mcf) |
10,927,477 | 10,731,248 | 33,559,096 | 34,160,329 | ||||||||||||
| Condensate (Bbls) |
105,517 | 85,988 | 259,145 | 345,726 | ||||||||||||
| Natural gas liquids (C3+) (Bbls) |
498,217 | 498,256 | 1,495,961 | 1,571,358 | ||||||||||||
| Ethane (Bbls) |
607,340 | 423,479 | 1,578,480 | 903,086 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Total (Mcfe)1 |
18,193,921 | 16,777,586 | 53,560,612 | 51,081,349 | ||||||||||||
| Production – average per day: |
||||||||||||||||
| Natural gas (Mcf) |
118,777 | 116,644 | 122,478 | 125,129 | ||||||||||||
| Condensate (Bbls) |
1,147 | 935 | 946 | 1,266 | ||||||||||||
| Natural gas liquids (C3+) (Bbls) |
5,415 | 5,416 | 5,460 | 5,756 | ||||||||||||
| Ethane (Bbls) |
6,602 | 4,603 | 5,761 | 3,308 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Total (Mcfe)1 |
197,760 | 182,365 | 195,477 | 187,111 | ||||||||||||
| Average price per unit: |
||||||||||||||||
| Realized natural gas price per Mcf – as reported |
$ | 1.54 | $ | 1.74 | $ | 1.44 | $ | 1.99 | ||||||||
| Realized impact from cash settled derivatives per Mcf |
0.11 | 0.83 | 0.73 | 0.68 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Net realized price per Mcf |
$ | 1.65 | $ | 2.57 | $ | 2.17 | $ | 2.67 | ||||||||
| Realized condensate price per Bbl – as reported |
$ | 38.82 | $ | 32.99 | $ | 34.72 | $ | 35.45 | ||||||||
| Realized impact from cash settled derivatives per Bbl2 |
0.88 | 31.33 | 8.46 | 25.48 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Net realized price per Bbl |
$ | 39.70 | $ | 64.32 | $ | 43.18 | $ | 60.93 | ||||||||
| Realized natural gas liquids (C3+) price per Bbl – as reported |
$ | 16.48 | $ | 10.17 | $ | 14.74 | $ | 15.83 | ||||||||
| Realized impact from cash settled derivatives per Bbl |
1.67 | 6.82 | 4.04 | 4.42 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Net realized price per Bbl |
$ | 18.15 | $ | 16.99 | $ | 18.78 | $ | 20.25 | ||||||||
| Realized ethane price per Bbl – as reported |
$ | 7.99 | $ | 7.22 | $ | 7.28 | $ | 6.82 | ||||||||
| Realized impact from cash settled derivatives per Bbl |
0.16 | 0.11 | 0.15 | 0.19 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Net realized price per Bbl |
$ | 8.15 | $ | 7.33 | $ | 7.43 | $ | 7.01 | ||||||||
| LOE/Mcfe |
$ | 1.45 | $ | 1.45 | $ | 1.42 | $ | 1.40 | ||||||||
| Cash G&A/Mcfe |
$ | 0.23 | $ | 0.28 | $ | 0.25 | $ | 0.31 | ||||||||
| 1 | Oil and natural gas liquids are converted at the rate of one barrel of oil equivalent to six Mcfe. |
| 2 | Includes the effect of derivatives not classified as discontinued operations. When including the effect of Illinois Basin production, derivatives realized increased prices by $0.87/bbl, $10.02/bbl, $3.85/bbl and $9.88/bbl for the three month periods ended September 30, 2016 and 2015 and the nine month periods ended September 30, 2016 and 2015, respectively. |
REX ENERGY CORPORATION
COMMODITY DERIVATIVES – HEDGE POSITION AS OF 8/1/2016
| 2016 | 2017 | |||||||
| Oil Derivatives (Bbls) | ||||||||
| Swap Contracts |
||||||||
| Volume |
20,000 | (1) | 21,000 | |||||
| Price |
$ | 44.00 | $ | 51.30 | ||||
| Collar Contracts |
||||||||
| Volume |
40,000 | 48,000 | ||||||
| Ceiling |
$ | 49.05 | $ | 57.20 | ||||
| Floor |
$ | 37.50 | $ | 45.00 | ||||
| Collar Contracts with Short Puts |
||||||||
| Volume |
40,000 | 48,000 | ||||||
| Ceiling |
$ | 44.50 | $ | 60.75 | ||||
| Floor |
$ | 35.50 | $ | 47.50 | ||||
| Short Put |
$ | 26.50 | $ | 37.50 | ||||
| Natural Gas Derivatives (Mcf) | ||||||||
| Swap Contracts |
||||||||
| Volume |
1,590,000 | (2) | 11,540,000 | (3) | ||||
| Price |
$ | 2.64 | $ | 3.00 | ||||
| Swaption Contracts |
||||||||
| Volume |
100,000 | — | ||||||
| Price |
$ | 3.15 | $ | — | ||||
| Put Spread Contracts |
||||||||
| Volume |
700,000 | — | ||||||
| Floor |
$ | 3.39 | $ | — | ||||
| Short Put |
$ | 2.61 | $ | — | ||||
| Collar Contracts with Short Puts |
||||||||
| Volume |
355,000 | 17,510,000 | ||||||
| Ceiling |
$ | 3.50 | $ | 3.87 | ||||
| Floor |
$ | 2.77 | $ | 3.01 | ||||
| Short Put |
$ | 2.18 | $ | 2.33 | ||||
| Call Contracts |
||||||||
| Volume |
— | 8,380,100 | ||||||
| Ceiling |
$ | — | $ | 4.51 | ||||
| Collar Contracts |
||||||||
| Volume |
560,000 | 1,700,000 | ||||||
| Ceiling |
$ | 2.96 | $ | 3.20 | ||||
| Floor |
$ | 2.56 | $ | 2.54 | ||||
| Natural Gas Liquids (Bbls) | ||||||||
| Swap Contracts |
||||||||
| Propane (C3) | ||||||||
| Volume |
156,000 | 312,000 | ||||||
| Price |
$ | 21.56 | $ | 18.04 | ||||
| Butane (C4) | ||||||||
| Volume |
38,000 | 108,000 | ||||||
| Price |
$ | 27.10 | $ | 23.80 | ||||
| Isobutane (IC4) | ||||||||
| Volume |
16,000 | 48,000 | ||||||
| Price |
$ | 27.93 | $ | 24.00 | ||||
| Natural Gasoline (C5+) | ||||||||
| Volume |
28,000 | 100,000 | ||||||
| Price |
$ | 50.00 | $ | 44.52 | ||||
| Ethane | ||||||||
| Volume |
110,000 | 540,000 | ||||||
| Price |
$ | 8.49 | $ | 10.13 | ||||
| Natural Gas Basis (Mcf) | ||||||||
| Swap Contracts |
||||||||
| Dominion Appalachia | ||||||||
| Volume |
1,147,000 | 10,755,000 | ||||||
| Price |
$ | (0.80 | ) | $ | (0.79 | ) | ||
| Texas Gas Zone 1 | ||||||||
| Volume |
— | 14,600,000 | ||||||
| Price |
$ | — | $ | (0.13 | ) | |||
| NYMEX Heating Oil (Gallon) | ||||||||
| Swap Contracts |
||||||||
| Volume |
2,000 | — | ||||||
| Price |
$ | 2.00 | $ | — |
| (1) | Includes 20,000 Bbls of enhanced swaps |
| (2) | Includes 0.4 Bcf of enhanced swaps |
| (3) | Includes 3.9 Bcf of enhanced swaps |
APPENDIX
REX ENERGY CORPORATION
NON-GAAP MEASURES
EBITDAX
“EBITDAX” means, for any period, the sum of net income for such period plus the following expenses, charges or income to the extent deducted from or added to net income in such period: interest, income taxes, DD&A, unrealized losses from financial derivatives, non-recurring gains and losses, exploration expenses and other similar non-cash charges, minus all non-cash income, including but not limited to, income from unrealized financial derivatives and gains on asset dispositions, added to net income. EBITDAX, as defined above, is used as a financial measure by our management team and by other users of its financial statements, such as our commercial bank lenders to analyze such things as:
| • | Our operating performance and return on capital in comparison to those of other companies in our industry, without regard to financial or capital structure; |
| • | The financial performance of our assets and valuation of the entity without regard to financing methods, capital structure or historical cost basis; |
| • | Our ability to generate cash sufficient to pay interest costs, support our indebtedness and make cash distributions to our stockholders; and |
| • | The viability of acquisitions and capital expenditure projects and the overall rates of return on alternative investment opportunities. |
EBITDAX is not a calculation based on GAAP financial measures and should not be considered as an alternative to net income (loss) (the most directly comparable GAAP financial measure) in measuring our performance, nor should it be used as an exclusive measure of cash flows, because it does not consider the impact of working capital growth, capital expenditures, debt principal reductions, and other sources and uses of cash, which are disclosed in our consolidated statements of cash flows.
We have reported EBITDAX because it is a financial measure used by our existing commercial lenders, and because this measure is commonly reported and widely used by investors as an indicator of a company’s operating performance and ability to incur and service debt. You should carefully consider the specific items included in our computations of EBITDAX. While we have disclosed EBITDAX to permit a more complete comparative analysis of our operating performance and debt servicing ability relative to other companies, you are cautioned that EBITDAX as reported by us may not be comparable in all instances to EBITDAX as reported by other companies. EBITDAX amounts may not be fully available for management’s discretionary use, due to requirements to conserve funds for capital expenditures, debt service and other commitments.
We believe that EBITDAX assists our lenders and investors in comparing our performance on a consistent basis without regard to certain expenses, which can vary significantly depending upon accounting methods. Because we may borrow money to finance our operations, interest expense is a necessary element of our costs. In addition, because we use capital assets, DD&A are also necessary elements of our costs. Finally, we are required to pay federal and state taxes, which are necessary elements of our costs. Therefore, any measures that exclude these elements have material limitations.
To compensate for these limitations, we believe it is important to consider both net income determined under GAAP and EBITDAX to evaluate our performance.
For purposes of consistency with current calculations, we have revised certain amounts relating to prior period EBITDAX. The following table presents a reconciliation of our net income to EBITDAX for each of the periods presented.
| Three Months Ended September 30, |
Nine Months Ended September 30, |
|||||||||||||||
| 2016 | 2015 | 2016 | 2015 | |||||||||||||
| Net Loss From Continuing Operations |
$ | (16,477 | ) | $ | (88,891 | ) | $ | (122,040 | ) | $ | (255,226 | ) | ||||
| Add Back (Less) Non-Recurring Costs (Income)1 |
8,306 | — | (6,388 | ) | 4,774 | |||||||||||
| Add Back Depletion, Depreciation, Amortization and Accretion |
15,109 | 20,832 | 46,371 | 67,369 | ||||||||||||
| Add Back (Less) Non-Cash Compensation Expense (Income) |
990 | (222 | ) | 2,006 | 4,413 | |||||||||||
| Add Back Interest Expense |
9,646 | 11,884 | 34,115 | 36,077 | ||||||||||||
| Add Back Impairment Expense |
9,563 | 85,193 | 45,344 | 209,880 | ||||||||||||
| Add Back Exploration Expenses |
216 | 580 | 1,954 | 1,774 | ||||||||||||
| Add Back (Less) (Gain) Loss on Disposal of Assets |
10 | (224 | ) | (4,285 | ) | (533 | ) | |||||||||
| Add Back (Less) (Gain) Loss on Financial Derivatives |
(16,866 | ) | (28,649 | ) | 8,254 | (45,487 | ) | |||||||||
| Add Back Cash Settlement of Derivatives |
2,145 | 15,082 | 32,485 | 40,102 | ||||||||||||
| Less Income Tax Benefit |
(8,106 | ) | — | (5,785 | ) | — | ||||||||||
| Add Back Non-Cash Portion of Equity Method Investments |
— | — | — | 406 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| EBITDAX From Continuing Operations |
$ | 4,536 | $ | 15,585 | $ | 32,031 | $ | 63,549 | ||||||||
| Net Income (Loss) From Discontinued Operations, Net of Income Taxes |
$ | 21,892 | $ | (5,785 | ) | $ | 12,719 | $ | (7,770 | ) | ||||||
| Income Attributable to Noncontrolling Interests |
— | 1 | — | (2,245 | ) | |||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Income (Loss) From Discontinued Operations Attributable to Rex Energy |
21,892 | (5,784 | ) | 12,719 | (10,015 | ) | ||||||||||
| Add Back Depletion, Depreciation, Amortization and Accretion |
18 | 6,294 | 5,100 | 15,497 | ||||||||||||
| Add Back (Less) Non-Cash Compensation Expense (Income) |
(366 | ) | 140 | (107 | ) | 421 | ||||||||||
| Add Back Interest Expense |
1 | 59 | 4 | 507 | ||||||||||||
| Add Back Impairment Expense |
— | 54,619 | 3,543 | 54,797 | ||||||||||||
| Add Back Exploration Expense |
— | 227 | 143 | 468 | ||||||||||||
| Less Gain on Disposal of Assets |
(30,491 | ) | (57,024 | ) | (30,535 | ) | (56,988 | ) | ||||||||
| Less Non-Cash Portion of Noncontrolling Interests |
— | (23 | ) | — | (209 | ) | ||||||||||
| Add Back Income Tax Expense |
8,354 | 2,416 | 7,852 | 2,658 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Add EBITDAX From Discontinued Operations |
$ | (592 | ) | $ | 924 | $ | (1,281 | ) | $ | 7,136 | ||||||
|
|
|
|
|
|
|
|
|
|||||||||
| EBITDAX (Non-GAAP) |
$ | 3,944 | $ | 16,509 | $ | 30,750 | $ | 70,685 | ||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| 1 | For the three and nine months ended September 30, 2016, includes approximately $8.3 million in expense related to a firm transportation agreement. During the third quarter of 2016, the company made a decision to cease all future development activities in the area associated with this firm transportation contract. For the three months ended September 30, 2016, includes $0.4 million in gains on the extinguishment of debt. For the nine months ended September 30, 2016, includes approximately $24.1 million in gains on the extinguishment of debt and $9.0 million in debt exchange expenses. For the three and nine months ended September 30, 2015, includes net fees incurred to terminate two drilling rig contracts earlier than their original term. |
Adjusted Net Income
“Adjusted Net Income” means, for any period, the sum of net income (loss) from continuing operations before income taxes for the period plus the following expenses, charges or income, in each case, to the extent deducted from or added to net income in the period: unrealized losses from financial derivatives, non-cash compensation expense, dry hole expenses, disposals of assets, impairment and other one-time or non-recurring charges, minus all gains from unrealized financial derivatives, disposal of assets and deferred income tax benefits, added to net income. Adjusted Net Income is used as a financial measure by Rex Energy’s management team and by other users of its financial statements, to analyze its financial performance without regard to non-cash deferred taxes and non-cash unrealized losses or gains from oil and gas derivatives. Adjusted Net Income is not a calculation based on GAAP financial measures and should not be considered as an alternative to net income (loss) in measuring the company’s performance.
Rex Energy reports Adjusted Net Income because it believes that this measure is commonly reported and widely used by investors as an indicator of a company’s operating performance. You should carefully consider the specific items included in the company’s computation of this measure. You are cautioned that Adjusted Net Income as reported by Rex Energy may not be comparable in all instances to that reported by other companies.
To compensate for these limitations, the company believes it is important to consider both net income determined under GAAP and Adjusted Net Income.
The following table presents a reconciliation of Rex Energy’s net income from continuing operations to its adjusted net income for each of the periods presented ($ in thousands):
| For the Three Months Ended September 30, |
For the Nine Months Ended September 30, |
|||||||||||||||
| 2016 | 2015 | 2016 | 2015 | |||||||||||||
| Loss From Continuing Operations Before Income Taxes, as reported |
$ | (24,583 | ) | $ | (88,891 | ) | $ | (127,825 | ) | $ | (255,226 | ) | ||||
| Gain (Loss) on Derivatives, Net |
(16,866 | ) | (28,649 | ) | 8,254 | (45,487 | ) | |||||||||
| Cash Settlement of Derivatives |
2,145 | 15,082 | 32,485 | 40,102 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Add Back (Less) Losses (Gains) from Financial Derivatives |
(14,721 | ) | (13,564 | ) | 40,739 | (5,385 | ) | |||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Add Back Non-Recurring Costs1 |
8,306 | — | (6,388 | ) | 4,774 | |||||||||||
| Add Back Impairment Expense |
9,563 | 85,193 | 45,344 | 209,880 | ||||||||||||
| Add Back Dry Hole Expense |
2 | — | 848 | 191 | ||||||||||||
| Add Back (Less) Non-Cash Compensation Expense (Income) |
990 | (222 | ) | 2,006 | 4,413 | |||||||||||
| Add Back (Less) (Gain) Loss on Disposal of Assets |
10 | (224 | ) | (4,285 | ) | (533 | ) | |||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Loss From Continuing Operations Before Income Taxes, adjusted |
$ | (20,433 | ) | $ | (17,708 | ) | $ | (49,561 | ) | $ | (41,886 | ) | ||||
| Less Income Tax Benefit, adjusted2 |
8,173 | 7,083 | 19,824 | 16,754 | ||||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Adjusted Net Loss From Continuing Operations |
$ | (12,260 | ) | $ | (10,625 | ) | $ | (29,737 | ) | $ | (25,132 | ) | ||||
| Basic – Adjusted Net Loss Per Share |
$ | (0.14 | ) | $ | (0.20 | ) | $ | (0.41 | ) | $ | (0.47 | ) | ||||
|
|
|
|
|
|
|
|
|
|||||||||
| Basic – Weighted Average Shares of Common Stock Outstanding |
90,803 | 53,936 | 73,098 | 53,748 | ||||||||||||
| 1 | For the three and nine months ended September 30, 2016, includes approximately $8.3 million in expense related to a firm transportation agreement. During the third quarter of 2016, the company made a decision to cease all future development activities in the area associated with this firm transportation contract. For the three months ended September 30, 2016, includes $0.4 million in gains on the extinguishment of debt. For the nine months ended September 30, 2016, includes approximately $24.1 million in gains on the extinguishment of debt and $9.0 million in debt exchange expenses. For the three and nine months ended September 30, 2015, includes net fees incurred to terminate two drilling rig contracts earlier than their original term. |
| 2 | Assumes an effective tax rate of 40% |
Cash General and Administrative Expenses
Cash General and Administrative Expenses (Cash G&A) is the difference between GAAP G&A and non-Cash G&A, which is primarily comprised of non-cash compensation expense. Rex Energy has reported Cash G&A because it believes that this measure is commonly reported and widely used by management and investors as an indicator of overhead efficiency without regard to non-cash expenditures, such as stock compensation. Cash G&A is not a calculation based on GAAP financial measures and should not be considered as an alternative to GAAP G&A in measuring the company’s performance. You should carefully consider the specific items included in the company’s computation of this measure. You are cautioned that Cash G&A as reported by Rex Energy may not be comparable in all instances to that reported by other companies.
To compensate for these limitations, the company believes it is important to consider both Cash G&A and GAAP G&A. The following table presents a reconciliation of Rex Energy’s GAAP G&A to its Cash G&A for each of the periods presented (in thousands):
| Three Months Ended September 30, |
Nine Months Ended September 30, |
|||||||||||||||
| 2016 | 2015 | 2016 | 2015 | |||||||||||||
| GAAP G&A |
$ | 5,116 | $ | 4,507 | $ | 15,237 | $ | 20,253 | ||||||||
| Non-Cash Compensation Expense |
990 | (222 | ) | 2,006 | 4,413 | |||||||||||
|
|
|
|
|
|
|
|
|
|||||||||
| Cash G&A |
$ | 4,126 | $ | 4,729 | $ | 13,231 | $ | 15,840 | ||||||||
Serious News for Serious Traders! Try StreetInsider.com Premium Free!
You May Also Be Interested In
- Get Up To 15% Flat Discount on Video Promotion Website on VideoIpsum
- AI Agent To Increase Email Deliverability With Woodpecker Integration: Launch
- Argo Blockchain PLC Announces Notice of Results
Create E-mail Alert Related Categories
SEC FilingsSign up for StreetInsider Free!
Receive full access to all new and archived articles, unlimited portfolio tracking, e-mail alerts, custom newswires and RSS feeds - and more!
