SM Energy Reports Second Quarter Of 2017 Results - Focus On Capital Efficiency Driving Value, Production Beats, Raising Guidance
DENVER, Aug. 3, 2017 /PRNewswire/ --
- Production beats expectations: 11.3 MMBoe, exceeding guidance due to well performance
- 11% growth from retained assets compared with the second quarter of 2016
- Full year 2017 production guidance increased by 0.8 MMBoe at the mid-point to 44.5-46.5 MMBoe
- Guidance reflects expected significant oil growth in the second half of 2017
- Capital efficiency drives value: First half of 2017 exceeds plan expectations for well performance and revenue at lower than expected drilling and completion costs
- Well tests continue to confirm RockStar acreage to east: Viper well peak 24-hour IP rate of 1,316 Boe/d, 91% oil
- Balance sheet remains strong: $1.5 B in liquidity
SM Energy Company ("SM Energy" or the "Company") (NYSE: SM) announced today financial results and operations highlights from the second quarter of 2017. The Company has revised its quarterly reporting format to include posting both an investor presentation and pre-recorded call in conjunction with this release. Please visit the Company's website at sm-energy.com to access this additional second quarter detail. The Company will host a webcast and conference call at 8:00 a.m. Mountain Time (10:00 a.m. Eastern Time) tomorrow, August 4, 2017, to answer questions. Further information on the earnings webcast and conference call can be found below.
MANAGEMENT COMMENTARY
President and Chief Executive Officer Jay Ottoson comments: "Our team continues to meet or exceed our operational objectives year-to-date. Our relentless pursuit of improved well performance and detailed approach to cost management have delivered high levels of efficiency in our capital investment program. As a result, year-to-date we have generated more production than we expected with less capital investment than we planned, and we are further increasing 2017 production guidance to reflect our projections for continued outperformance."
SECOND QUARTER 2017 RESULTS
PRODUCTION - SEQUENTIAL COMPARISON:
| COMPANY PRODUCTION |
||||||||
| Second Quarter |
First Quarter |
% Change |
||||||
| Total Company (MMBoe) |
11.3 |
12.1 |
||||||
| Assets sold (MMBoe) |
— |
(1.5) |
||||||
| Retained Assets (MMBoe) |
11.3 |
10.6 |
||||||
| By commodity |
||||||||
| Oil (MMBbls) |
2.9 |
3.0 |
(4)% |
|||||
| Natural gas (Bcf) |
34.0 |
30.8 |
10% |
|||||
| NGLs (MMBbls) |
2.8 |
2.4 |
13% |
|||||
| Retained Assets (MMBoe) |
11.3 |
10.6 |
7% |
|||||
| By region (MMBoe) |
||||||||
| Eagle Ford (operated) |
8.0 |
7.3 |
10% |
|||||
| Permian Basin |
2.3 |
2.1 |
8% |
|||||
| Rocky Mountain |
1.1 |
1.2 |
(12)% |
|||||
| Retained Assets (MMBoe) |
11.3 |
10.6 |
7% |
|||||
| • |
Total Company production includes production from assets sold (through the closing date) |
| • |
Eagle Ford (operated) includes nominal other production from the region |
Second quarter production of 11.3 MMBoe is up 7% sequentially and up 11% compared with the second quarter of 2016, on a retained asset basis. Production in the second quarter of 2017 reflects the acceleration of 11 well completions in the Eagle Ford (as announced on June 6, 2017), and further exceeds guidance due to continued production outperformance from new wells in both the Permian Basin and Eagle Ford. As a result of second quarter production outperformance, the Company is raising full year production guidance by 0.8 MMBoe. For the first six months of 2017, production was 23.4 MMBoe.
In the second quarter of 2017, the average realized price per Boe before the effects of commodity hedges was $25.13 and after the effects of commodity hedges was $26.57. Cash production costs totaled $10.98 per Boe, down sequentially from $11.42 per Boe in the first quarter of 2017 and up from $10.38 per Boe in the second quarter of 2016. The Company is updating its guidance for the second half of 2017 to reflect modified LOE and transportation costs associated with retaining its Divide County, North Dakota assets. Please see guidance below.
Net loss for the second quarter of 2017 was $119.9 million, or $1.08 per diluted common share, compared with a net loss of $168.7 million, or $2.48 per diluted common share, in the second quarter of 2016. Net loss in the second quarter of 2017 reflects a 43% increase in the Company's pre-hedge cash operating margin per Boe from the prior year period. The 2017 period also includes a reduction in DD&A expense per Boe from $14.75 to $13.52, a loss on divestiture activity of $167.1 million and a non-cash derivative gain of $38.9 million. Net cash provided by operating activities in the second quarter of 2017 was $107.1 million. For the first six months of 2017, net loss was $45.5 million, or $0.41 per diluted common share, and net cash provided by operating activities was $242.1 million.
As discussed below, adjusted EBITDAX, adjusted net income (loss) and adjusted net income (loss) per diluted common share are non-GAAP measures. Please reference the reconciliations to the most directly comparable GAAP financial measures at the end of this release.
Adjusted EBITDAX for the second quarter of 2017 was $154.1 million, compared with $217.1 million in the prior year period. While the pre-hedge operating margin was significantly higher in the second quarter of 2017, the prior year period benefited from a $101.7 million derivative settlement gain. For the first six months of 2017, adjusted EBITDAX was $326.3 million.
Adjusted net loss for the second quarter was $35.5 million, or $0.32 per diluted common share, compared with an adjusted net loss of $30.2 million, or $0.44 per diluted common share, in the second quarter of 2016. For the first six months of 2017, adjusted net loss was $55.2 million, or $0.50 per diluted common share. The calculation of adjusted net loss excludes non-recurring items and items difficult to estimate in order to present results that can be more consistently compared with prior periods and peer results.
FINANCIAL POSITION AND LIQUIDITY
At June 30, 2017, the outstanding principal balance on the Company's long-term debt included $2.8 billion in senior notes plus $172.5 million in senior convertible notes, with zero drawn on the Company's senior secured credit facility. At quarter-end, the Company had a cash balance of $559.5 million, providing for net debt of $2.4 billion. The Company's undrawn credit facility plus cash on hand provide $1.5 billion in liquidity.
CAPITAL ACTIVITY AND OPERATIONS
Costs incurred for the second quarter of 2017 were $258.0 million, which included $15.7 million of primarily unproved property acquisitions. Second quarter total capital spend (see below for GAAP reconciliation) was $237.3 million. During the quarter, the Company drilled or participated in 30 net wells and completed or participated in 25 net wells. For the first six months of 2017, costs incurred were $515.0 million and total capital spend was $430.2 million.
Please refer to the Total Capital Spend Reconciliation at the end of this release for a reconciliation to Costs Incurred in oil and gas activities (GAAP).
PERMIAN BASIN
In the second quarter of 2017, production from the Company's Midland Basin assets was 2.3 MMBoe and was 75% oil. The Company is currently running seven horizontal rigs in the basin, with two in the Sweetie Peck area and five in the RockStar area. The Company recently converted the single vertical rig operating in the RockStar area to horizontal drilling, and is currently running three completion crews. During the second quarter, the Company drilled 23 net operated wells and had nine net flowing completions. The second quarter production margin for this area was $28.75 per Boe.
Subsequent to quarter-end, the Viper well, located in the northern portion of the Company's RockStar acreage, reached a 24-hour peak initial production rate of 1,316 Boe/d. The Viper well is drilled into the Wolfcamp A with a 10,400 foot lateral. Similar to peer wells in the area, the Viper well demonstrates a lower peak rate combined with a flatter production profile. In combination with nearby peer wells, the area now supports economic wells in the Wolfcamp A (SM, Sabalo), Wolfcamp B (Apache) and Lower Spraberry (Sabalo).
The Company remains focused on optimizing drilling and completion operations across the basin in order to identify the appropriate number of wells per section and optimize production performance in preparation for increased development activity in 2018. Over the past year, the Company has collected approximately 3,500 feet of core to better understand the entire Spraberry through Wolfcamp column, gather geomechanical rock properties necessary to support reservoir simulation efforts, and evaluate untested intervals. Efforts to drive capital efficiency and optimization also include drilling longer laterals and pad drilling. The Company has just completed the first 10,000 foot laterals at Sweetie Peck and has just completed the first six well pad at RockStar that co-develops the Lower Spraberry and Wolfcamp A.
The Company currently has approximately 89,000 net acres in the Midland Basin, which includes approximately 5,400 additional net acres acquired year-to-date through acreage trades and other transactions.
EAGLE FORD
In the second quarter of 2017, production from the Company's operated Eagle Ford assets was 8.0 MMBoe and included 62% natural gas, 34% NGLs, and 4% oil. Production was up 9.5% sequentially as the Company accelerated activity in the area. The Company is currently running one horizontal rig with plans to add a second horizontal rig during the third quarter in the Eagle Ford. During the second quarter, the Company drilled six and completed 14 net wells, including acceleration of 11 completions into the second quarter.
The Company's focus on drilling and completion optimization continues to drive better results in the Eagle Ford where completions year-to-date are exceeding type curve expectations and driving higher production. For example in the North Area, pad completions in the first half of 2017 included tighter stage and cluster spacing with increased fluid. The Company's current drilling plan co-develops the lower and upper Eagle Ford (see associated investor presentation for graph). In the East Area, pad completions included higher sand loadings and tighter stage spacing. Wells are downspaced to 625 feet (from 900 feet) and continue to outperform the 900 foot spacing type curve.
The Company operates approximately 167,500 net acres in its Eagle Ford program.
ROCKY MOUNTAIN
In the Powder River Basin, the Company is working with a third party to test newer generation drilling and completion techniques in the Shannon and Frontier zones. To-date, well results are very positive and the Company anticipates continuing its relationship with the third party into 2018.
During the second quarter, the Company decided to retain its Divide County assets (previously held for sale) rather than sell the assets due to market conditions.
GUIDANCE
Full year 2017 guidance is revised as follows:
- Total capital spend (before acquisitions) ($MM) $875 (unchanged)
- Total production (MMBoe) 44.5-46.5
- Increased 0.8 MMBoe at the mid-point
- Oil percent near 30% of commodity mix, full year average
- LOE including ad valorem ($/Boe) $4.30-4.60
- Increased to include retention of Divide County
- Transportation ($/Boe) $5.40-5.65
- Reduced $0.10 at the midpoint
- Production taxes ($/Boe/percent of pre-hedge revenue) ~$1.10/4.0-4.5%
- G&A ($MM) $115-125
- Reduced $5 MM at the mid-point
- Includes approximately $20 MM non-cash, stock-based compensation expense
- Capitalized overhead/Exploration before dry hole expenses ($MM) $65-70 (unchanged)
- This amount is a component of capital guidance
- DD&A ($/Boe) $12.00-14.00
Third quarter of 2017 production is expected to range between 10.8 and 11.2 MMBoe, which will vary depending upon the ultimate timing of capital activity, at approximately 29-30% oil in the commodity mix.
Total capital spend (before acquisitions) is a non-GAAP measure. The Company is unable to present a quantitative reconciliation of this forward-looking non-GAAP financial measure without unreasonable effort because acquisition costs are inherently unpredictable.
COMMODITY DERIVATIVES
As of August 1, 2017.
For the second half of 2017, the Company has commodity derivatives in place for approximately 60% of expected oil production, 75% of expected natural gas production and 80% of expected NGL production. For 2018, approximately one-half of total expected production volumes are hedged.
| OIL SWAPS |
OIL COLLARS |
NATURAL GAS SWAPS |
NGL SWAPS |
|
| Volume/Average |
Volume/Avg. Ceiling - Floor |
Volume /Average Price |
Volume/Average |
|
| Period |
(MBbls/$Bbl) |
(MBbls/$Bbl) |
(BBtu/$MMBtu) |
(MBbls/$Bbl) |
| 3Q17 |
1,340/$46.66 |
583/$54.05 - $45.00 |
23,657/$4.01 |
2,019/$20.89 |
| 4Q17 |
1,254/$46.35 |
1,086/$56.05 - $47.51 |
22,001/$3.98 |
1,996/$20.18 |
| 1Q18 |
535/$49.32 |
1,026/$58.46 - $50.00 |
19,628/$3.25 |
1,829/$21.45 |
| 2Q18 |
910/$48.57 |
1,004/$58.37 - $50.00 |
13,052/$2.85 |
1,437/$16.26 |
| 3Q18 |
993/$48.79 |
1,393/$57.93 - $50.00 |
14,241/$2.87 |
1,662/$16.47 |
| 4Q18 |
1,034/$48.89 |
1,607/$57.75 - $50.00 |
15,487/$2.90 |
1,828/$16.54 |
| Notes: The volumes above represent fixed swap and collar contracts the Company has in place through 4Q18. Volumes for 3Q17 include all commodity contracts for settlement any time during the third quarter of 2017; prices are weighted averages; natural gas contracts reflect regional contract positions and are no longer adjusted to a NYMEX equivalent; NGL prices are at Mt. Belvieu and reflect specific NGL components, 2017 and 2018 quarters include ethane, propane, butanes and gasoline. In addition to the volumes above, the Company has oil basis swaps in place. See 2Q17 Earnings Presentation for contract details on the oil basis swaps. |
UPCOMING EVENTS
EARNINGS WEBCAST AND CALL
As previously announced, SM Energy is posting a pre-recorded discussion and presentation in conjunction with this earnings release. Please look for the additional detail on our website at www.sm-energy.com. Tomorrow morning, the Company will host a second quarter financial and operating results Q&A session via webcast and conference call. Please join management at 8:00 a.m. Mountain Time/10:00 a.m. Eastern Time August 4, 2017. Join us via webcast at www.sm-energy.com or by telephone 877-870-4263 (toll free) or 412-317-0790 (international), and indicate SM Energy earnings call. The webcast and call will also be available for replay. The dial-in replay number is 877-344-7529 (toll free).
UPCOMING CONFERENCE PARTICIPATION
- August 15, 2017 - Enercom: The Oil and Gas Conference 22. President and Chief Executive Officer Jay Ottoson will present at 10:05 a.m. Mountain time. This event will be webcast. An investor presentation for this event will be posted to the Company's website on August 14, 2017.
- September 6, 2017 - Barclays CEO Energy-Power Conference. President and Chief Executive Officer Jay Ottoson will present at 11:45 a.m. Eastern time. This event will be webcast. An investor presentation for this event will be posted to the Company's website on September 5, 2017.
FORWARD LOOKING STATEMENTS
This release contains forward-looking statements within the meaning of securities laws. These statements involve known and unknown risks, which may cause SM Energy's actual results to differ materially from results expressed or implied by the forward-looking statements. Forward-looking statements in this release include, among other things, guidance estimates for the third quarter and full year 2017. General risk factors include the availability, proximity and capacity of gathering, processing and transportation facilities; the volatility and level of oil, natural gas, and natural gas liquids prices, including any impact on the Company's asset carrying values or reserves arising from price declines; uncertainties inherent in projecting future rates of production or other results from drilling and completion activities; the imprecise nature of estimating oil and gas reserves; uncertainties inherent in projecting future drilling and completion activities, costs or results; the uncertain nature of divestiture, joint venture, farm down or similar efforts and the ability to complete any such transactions; the uncertain nature of expected benefits from the actual or expected divestiture, joint venture, farm down or similar efforts; the availability of additional economically attractive exploration, development, and acquisition opportunities for future growth and any necessary financings; unexpected drilling conditions and results; unsuccessful exploration and development drilling results; the availability of drilling, completion, and operating equipment and services; the risks associated with the Company's commodity price risk management strategy; uncertainty regarding the ultimate impact of potentially dilutive securities; and other such matters discussed in the "Risk Factors" section of SM Energy's 2016 Annual Report on Form 10-K, as such risk factors may be updated from time to time in the Company's other periodic reports filed with the Securities and Exchange Commission. The forward-looking statements contained herein speak as of the date of this announcement. Although SM Energy may from time to time voluntarily update its prior forward-looking statements, it disclaims any commitment to do so except as required by securities laws.
ABOUT THE COMPANY
SM Energy Company is an independent energy company engaged in the acquisition, exploration, development, and production of crude oil, natural gas, and natural gas liquids in onshore North America. SM Energy routinely posts important information about the Company on its website. For more information about SM Energy, please visit its website at www.SM-Energy.com.
SM ENERGY CONTACTS
INVESTORS: Jennifer Martin Samuels, [email protected], 303-864-2507
| SM ENERGY COMPANY |
|||||||||||||||||||||
| FINANCIAL HIGHLIGHTS (UNAUDITED) |
|||||||||||||||||||||
| June 30, 2017 |
|||||||||||||||||||||
| For the Three Months Ended |
For the Six Months Ended |
||||||||||||||||||||
| Production Data |
2017 |
2016 |
Percent Change |
2017 |
2016 |
Percent Change |
|||||||||||||||
| Average realized sales price, before the effects of derivative settlements: |
|||||||||||||||||||||
| Oil (per Bbl) |
$ |
44.30 |
$ |
39.38 |
12% |
$ |
46.08 |
$ |
32.51 |
42% |
|||||||||||
| Gas (per Mcf) |
2.99 |
1.79 |
67% |
2.99 |
1.83 |
63% |
|||||||||||||||
| NGLs (per Bbl) |
19.71 |
16.12 |
22% |
20.92 |
14.05 |
49% |
|||||||||||||||
| Equivalent (per BOE) |
$ |
25.13 |
$ |
20.35 |
23% |
$ |
26.38 |
$ |
18.14 |
45% |
|||||||||||
| Average realized sales price, including the effects of derivative settlements: |
|||||||||||||||||||||
| Oil (per Bbl) |
$ |
43.36 |
$ |
56.97 |
(24)% |
$ |
44.24 |
$ |
53.45 |
(17)% |
|||||||||||
| Gas (per Mcf) |
3.63 |
2.60 |
40% |
3.56 |
2.80 |
27% |
|||||||||||||||
| NGLs (per Bbl) |
18.73 |
15.61 |
20% |
18.96 |
14.63 |
30% |
|||||||||||||||
| Equivalent (per BOE) |
$ |
26.57 |
$ |
27.45 |
(3)% |
$ |
27.08 |
$ |
27.11 |
—% |
|||||||||||
| Production: |
|||||||||||||||||||||
| Oil (MMBbl) |
2.9 |
4.1 |
(29)% |
6.4 |
8.2 |
(22)% |
|||||||||||||||
| Gas (Bcf) |
34.0 |
39.0 |
(13)% |
67.9 |
74.7 |
(9)% |
|||||||||||||||
| NGLs (MMBbl) |
2.8 |
3.7 |
(26)% |
5.7 |
7.1 |
(20)% |
|||||||||||||||
| MMBOE (6:1) |
11.3 |
14.3 |
(21)% |
23.4 |
27.7 |
(15)% |
|||||||||||||||
| Average daily production: |
|||||||||||||||||||||
| Oil (MBbl/d) |
32.0 |
45.1 |
(29)% |
35.5 |
45.2 |
(21)% |
|||||||||||||||
| Gas (MMcf/d) |
374.1 |
428.2 |
(13)% |
375.3 |
410.2 |
(9)% |
|||||||||||||||
| NGLs (MBbl/d) |
30.3 |
40.8 |
(26)% |
31.4 |
38.8 |
(19)% |
|||||||||||||||
| MBOE/d (6:1) |
124.6 |
157.2 |
(21)% |
129.5 |
152.4 |
(15)% |
|||||||||||||||
| Per BOE data: |
|||||||||||||||||||||
| Realized price, before the effects of derivative settlements |
$ |
25.13 |
$ |
20.35 |
23% |
$ |
26.38 |
$ |
18.14 |
45% |
|||||||||||
| Lease operating expense |
4.11 |
3.31 |
24% |
3.96 |
3.54 |
12% |
|||||||||||||||
| Transportation costs |
5.71 |
5.95 |
(4)% |
5.79 |
6.00 |
(4)% |
|||||||||||||||
| Production taxes |
1.00 |
0.93 |
8% |
1.09 |
0.80 |
36% |
|||||||||||||||
| Ad valorem tax expense |
0.16 |
0.19 |
(16)% |
0.36 |
0.23 |
57% |
|||||||||||||||
| General and administrative (excluding stock-compensation) |
2.21 |
1.60 |
38% |
2.15 |
1.80 |
19% |
|||||||||||||||
| Net, before the effects of derivative settlements |
$ |
11.94 |
$ |
8.37 |
43% |
$ |
13.03 |
$ |
5.77 |
126% |
|||||||||||
| Derivative settlement gain |
1.44 |
7.10 |
(80)% |
0.70 |
8.97 |
(92)% |
|||||||||||||||
| Margin, including the effects of derivative settlements |
$ |
13.38 |
$ |
15.47 |
(14)% |
$ |
13.73 |
$ |
14.74 |
(7)% |
|||||||||||
| Depletion, depreciation, amortization, and asset retirement obligation liability accretion |
$ |
13.52 |
$ |
14.75 |
(8)% |
$ |
12.42 |
$ |
15.34 |
(19)% |
|||||||||||
| SM ENERGY COMPANY |
|||||||
| FINANCIAL HIGHLIGHTS (UNAUDITED) |
|||||||
| June 30, 2017 |
|||||||
| Condensed Consolidated Balance Sheets |
|||||||
| (in thousands, except share amounts) |
June 30, |
December 31, |
|||||
| ASSETS |
2017 |
2016 |
|||||
| Current assets: |
|||||||
| Cash and cash equivalents |
$ |
559,521 |
$ |
9,372 |
|||
| Accounts receivable |
105,713 |
151,950 |
|||||
| Derivative asset |
85,962 |
54,521 |
|||||
| Prepaid expenses and other |
18,121 |
8,799 |
|||||
| Total current assets |
769,317 |
224,642 |
|||||
| Property and equipment (successful efforts method): |
|||||||
| Total property and equipment, net |
5,346,411 |
6,081,354 |
|||||
| Noncurrent assets: |
|||||||
| Derivative asset |
82,194 |
67,575 |
|||||
| Other noncurrent assets |
14,683 |
19,940 |
|||||
| Total other noncurrent assets |
96,877 |
87,515 |
|||||
| Total Assets |
$ |
6,212,605 |
$ |
6,393,511 |
|||
| LIABILITIES AND STOCKHOLDERS' EQUITY |
|||||||
| Current liabilities: |
|||||||
| Accounts payable and accrued expenses |
$ |
311,476 |
$ |
299,708 |
|||
| Derivative liability |
36,296 |
115,464 |
|||||
| Total current liabilities |
347,772 |
415,172 |
|||||
| Noncurrent liabilities: |
|||||||
| Revolving credit facility |
— |
— |
|||||
| Senior Notes, net of unamortized deferred financing costs |
2,767,030 |
2,766,719 |
|||||
| Senior Convertible Notes, net of unamortized discount and deferred financing costs |
134,918 |
130,856 |
|||||
| Asset retirement obligation |
100,304 |
96,134 |
|||||
| Asset retirement obligation associated with oil and gas properties held for sale |
234 |
26,241 |
|||||
| Deferred income taxes |
245,506 |
315,672 |
|||||
| Derivative liability |
69,915 |
98,340 |
|||||
| Other noncurrent liabilities |
45,098 |
47,244 |
|||||
| Total noncurrent liabilities |
3,363,005 |
3,481,206 |
|||||
| Stockholders' equity: |
|||||||
| Common stock, $0.01 par value - authorized: 200,000,000 shares; issued and outstanding: 111,453,476 and 111,257,500 shares, respectively |
1,115 |
1,113 |
|||||
| Additional paid-in capital |
1,729,104 |
1,716,556 |
|||||
| Retained earnings |
786,608 |
794,020 |
|||||
| Accumulated other comprehensive loss |
(14,999) |
(14,556) |
|||||
| Total stockholders' equity |
2,501,828 |
2,497,133 |
|||||
| Total Liabilities and Stockholders' Equity |
$ |
6,212,605 |
$ |
6,393,511 |
|||
| SM ENERGY COMPANY |
|||||||||||||||
| FINANCIAL HIGHLIGHTS (UNAUDITED) |
|||||||||||||||
| June 30, 2017 |
|||||||||||||||
| Condensed Consolidated Statements of Operations |
|||||||||||||||
| (in thousands, except per share amounts) |
For the Three Months Ended |
For the Six Months Ended |
|||||||||||||
| 2017 |
2016 |
2017 |
2016 |
||||||||||||
| Operating revenues and other income: |
|||||||||||||||
| Oil, gas, and NGL production revenue |
$ |
284,939 |
$ |
291,142 |
$ |
618,137 |
$ |
502,965 |
|||||||
| Net gain (loss) on divestiture activity |
(167,133) |
50,046 |
(129,670) |
(18,975) |
|||||||||||
| Other operating revenues |
2,915 |
626 |
4,992 |
900 |
|||||||||||
| Total operating revenues and other income |
120,721 |
341,814 |
493,459 |
484,890 |
|||||||||||
| Operating expenses: |
|||||||||||||||
| Oil, gas, and NGL production expense |
124,376 |
148,591 |
262,422 |
293,134 |
|||||||||||
| Depletion, depreciation, amortization, and asset retirement obligation liability accretion |
153,232 |
211,020 |
291,044 |
425,227 |
|||||||||||
| Exploration |
13,072 |
13,187 |
25,050 |
28,460 |
|||||||||||
| Impairment of proved properties |
3,806 |
— |
3,806 |
269,785 |
|||||||||||
| Abandonment and impairment of unproved properties |
157 |
38 |
157 |
2,349 |
|||||||||||
| General and administrative |
28,460 |
28,200 |
57,684 |
60,438 |
|||||||||||
| Net derivative (gain) loss |
(55,189) |
163,351 |
(169,963) |
149,123 |
|||||||||||
| Other operating expenses |
445 |
7,976 |
5,304 |
13,648 |
|||||||||||
| Total operating expenses |
268,359 |
572,363 |
475,504 |
1,242,164 |
|||||||||||
| Income (loss) from operations |
(147,638) |
(230,549) |
17,955 |
(757,274) |
|||||||||||
| Non-operating income (expense): |
|||||||||||||||
| Interest expense |
(44,595) |
(34,035) |
(91,548) |
(65,123) |
|||||||||||
| Gain (loss) on extinguishment of debt |
— |
— |
(35) |
15,722 |
|||||||||||
| Other, net |
1,265 |
5 |
1,600 |
11 |
|||||||||||
| Loss before income taxes |
(190,968) |
(264,579) |
(72,028) |
(806,664) |
|||||||||||
| Income tax benefit |
71,061 |
95,898 |
26,555 |
290,773 |
|||||||||||
| Net loss |
$ |
(119,907) |
$ |
(168,681) |
$ |
(45,473) |
$ |
(515,891) |
|||||||
| Basic weighted-average common shares outstanding |
111,277 |
68,102 |
111,274 |
68,090 |
|||||||||||
| Diluted weighted-average common shares outstanding |
111,277 |
68,102 |
111,274 |
68,090 |
|||||||||||
| Basic net loss per common share |
$ |
(1.08) |
$ |
(2.48) |
$ |
(0.41) |
$ |
(7.58) |
|||||||
| Diluted net loss per common share |
$ |
(1.08) |
$ |
(2.48) |
$ |
(0.41) |
$ |
(7.58) |
|||||||
| (1) Non-cash stock-based compensation component included in: |
|||||||||||||||
| Exploration expense |
$ |
995 |
$ |
1,785 |
$ |
2,403 |
$ |
3,447 |
|||||||
| G&A expense |
$ |
3,363 |
$ |
5,262 |
$ |
7,410 |
$ |
10,468 |
|||||||
| (2) The net derivative (gain) loss line item consists of the following: |
|||||||||||||||
| Settlement gain |
$ |
(16,303) |
$ |
(101,710) |
$ |
(16,310) |
$ |
(248,738) |
|||||||
| (Gain) loss on fair value changes |
$ |
(38,886) |
$ |
265,061 |
$ |
(153,653) |
$ |
397,861 |
|||||||
| Total net derivative (gain) loss |
$ |
(55,189) |
$ |
163,351 |
$ |
(169,963) |
$ |
149,123 |
|||||||
| SM ENERGY COMPANY |
||||||||||||||||||||||
| FINANCIAL HIGHLIGHTS (UNAUDITED) |
||||||||||||||||||||||
| June 30, 2017 |
||||||||||||||||||||||
| Condensed Consolidated Statement of Stockholders' Equity |
||||||||||||||||||||||
| (in thousands, except share amounts) |
||||||||||||||||||||||
| Additional |
Accumulated |
Total Stockholders' |
||||||||||||||||||||
| Common Stock |
Retained |
|||||||||||||||||||||
| Shares |
Amount |
|||||||||||||||||||||
| Balances, December 31, 2016 |
111,257,500 |
$ |
1,113 |
$ |
1,716,556 |
$ |
794,020 |
$ |
(14,556) |
$ |
2,497,133 |
|||||||||||
| Net loss |
— |
— |
— |
(45,473) |
— |
(45,473) |
||||||||||||||||
| Other comprehensive loss |
— |
— |
— |
— |
(443) |
(443) |
||||||||||||||||
| Cash dividends, $ 0.05 per share |
— |
— |
— |
(5,563) |
— |
(5,563) |
||||||||||||||||
| Issuance of common stock under Employee Stock Purchase Plan |
123,678 |
1 |
1,737 |
— |
— |
1,738 |
||||||||||||||||
| Issuance of common stock upon vesting of restricted stock units, net of shares used for tax withholdings |
725 |
— |
(11) |
— |
— |
(11) |
||||||||||||||||
| Stock-based compensation expense |
71,573 |
1 |
9,812 |
— |
— |
9,813 |
||||||||||||||||
| Cumulative effect of accounting change |
— |
— |
1,108 |
43,624 |
— |
44,732 |
||||||||||||||||
| Other |
— |
— |
(98) |
— |
— |
(98) |
||||||||||||||||
| Balances, June 30, 2017 |
111,453,476 |
$ |
1,115 |
$ |
1,729,104 |
$ |
786,608 |
$ |
(14,999) |
$ |
2,501,828 |
|||||||||||
| SM ENERGY COMPANY |
|||||||||||||||
| FINANCIAL HIGHLIGHTS (UNAUDITED) |
|||||||||||||||
| June 30, 2017 |
|||||||||||||||
| Condensed Consolidated Statements of Cash Flows |
|||||||||||||||
| (in thousands) |
For the Three Months |
For the Six Months |
|||||||||||||
| 2017 |
2016 |
2017 |
2016 |
||||||||||||
| Cash flows from operating activities: |
|||||||||||||||
| Net loss |
$ |
(119,907) |
$ |
(168,681) |
$ |
(45,473) |
$ |
(515,891) |
|||||||
| Adjustments to reconcile net loss to net cash provided by operating activities: |
|||||||||||||||
| Net (gain) loss on divestiture activity |
167,133 |
(50,046) |
129,670 |
18,975 |
|||||||||||
| Depletion, depreciation, amortization, and asset retirement obligation liability accretion |
153,232 |
211,020 |
291,044 |
425,227 |
|||||||||||
| Impairment of proved properties |
3,806 |
— |
3,806 |
269,785 |
|||||||||||
| Abandonment and impairment of unproved properties |
157 |
38 |
157 |
2,349 |
|||||||||||
| Stock-based compensation expense |
4,358 |
7,047 |
9,813 |
13,915 |
|||||||||||
| Net derivative (gain) loss |
(55,189) |
163,351 |
(169,963) |
149,123 |
|||||||||||
| Derivative settlement gain |
16,303 |
101,710 |
16,310 |
248,738 |
|||||||||||
| Amortization of debt discount and deferred financing costs |
3,733 |
2,850 |
8,679 |
1,930 |
|||||||||||
| Non-cash (gain) loss on extinguishment of debt, net |
— |
— |
22 |
(15,722) |
|||||||||||
| Deferred income taxes |
(64,015) |
(95,975) |
(30,790) |
(291,014) |
|||||||||||
| Plugging and abandonment |
(418) |
(2,112) |
(1,609) |
(2,716) |
|||||||||||
| Other, net |
(2,300) |
3,668 |
2,267 |
2,517 |
|||||||||||
| Changes in current assets and liabilities: |
|||||||||||||||
| Accounts receivable |
16,586 |
(38,142) |
46,993 |
(11,220) |
|||||||||||
| Prepaid expenses and other |
(9,499) |
3,503 |
(9,321) |
8,487 |
|||||||||||
| Accounts payable and accrued expenses |
(3,476) |
(9,433) |
(8,973) |
(61,727) |
|||||||||||
| Accrued derivative settlements |
(3,355) |
9,799 |
(517) |
14,117 |
|||||||||||
| Net cash provided by operating activities |
107,149 |
138,597 |
242,115 |
256,873 |
|||||||||||
| Cash flows from investing activities: |
|||||||||||||||
| Net proceeds from the sale of oil and gas properties |
21,914 |
11,761 |
766,247 |
12,967 |
|||||||||||
| Capital expenditures |
(212,342) |
(169,200) |
(366,743) |
(345,570) |
|||||||||||
| Acquisition of proved and unproved oil and gas properties |
(13,035) |
(2,707) |
(88,140) |
(17,751) |
|||||||||||
| Other, net |
514 |
(1,785) |
3,000 |
(900) |
|||||||||||
| Net cash provided by (used in) investing activities |
(202,949) |
(161,931) |
314,364 |
(351,254) |
|||||||||||
| Cash flows from financing activities: |
|||||||||||||||
| Proceeds from credit facility |
8,500 |
268,000 |
406,000 |
585,000 |
|||||||||||
| Repayment of credit facility |
(8,500) |
(230,500) |
(406,000) |
(456,500) |
|||||||||||
| Debt issuance costs related to credit facility |
— |
(3,132) |
— |
(3,132) |
|||||||||||
| Cash paid to repurchase Senior Notes |
— |
(9,987) |
(2,344) |
(29,904) |
|||||||||||
| Net proceeds from sale of common stock |
1,738 |
2,354 |
1,738 |
2,354 |
|||||||||||
| Dividends paid |
(5,563) |
(3,404) |
(5,563) |
(3,404) |
|||||||||||
| Other, net |
(1) |
(30) |
(161) |
(33) |
|||||||||||
| Net cash provided by (used in) financing activities |
(3,826) |
23,301 |
(6,330) |
94,381 |
|||||||||||
| Net change in cash and cash equivalents |
(99,626) |
(33) |
550,149 |
— |
|||||||||||
| Cash and cash equivalents at beginning of period |
659,147 |
51 |
9,372 |
18 |
|||||||||||
| Cash and cash equivalents at end of period |
$ |
559,521 |
$ |
18 |
$ |
559,521 |
$ |
18 |
|||||||
| SM ENERGY COMPANY |
|||||||||||||||
| FINANCIAL HIGHLIGHTS (UNAUDITED) |
|||||||||||||||
| June 30, 2017 |
|||||||||||||||
| Adjusted EBITDAX(1) |
|||||||||||||||
| (in thousands) |
|||||||||||||||
| Reconciliation of net loss (GAAP) to adjusted EBITDAX (Non-GAAP) to net cash provided by operating activities (GAAP) |
For the Three Months Ended |
For the Six Months Ended |
|||||||||||||
| 2017 |
2016 |
2017 |
2016 |
||||||||||||
| Net loss (GAAP) |
$ |
(119,907) |
$ |
(168,681) |
$ |
(45,473) |
$ |
(515,891) |
|||||||
| Interest expense |
44,595 |
34,035 |
91,548 |
65,123 |
|||||||||||
| Other non-operating income, net |
(1,265) |
(5) |
(1,600) |
(11) |
|||||||||||
| Income tax benefit |
(71,061) |
(95,898) |
(26,555) |
(290,773) |
|||||||||||
| Depletion, depreciation, amortization, and asset retirement obligation liability accretion |
153,232 |
211,020 |
291,044 |
425,227 |
|||||||||||
| Exploration(2) |
12,077 |
11,402 |
22,647 |
25,013 |
|||||||||||
| Impairment of proved properties |
3,806 |
— |
3,806 |
269,785 |
|||||||||||
| Abandonment and impairment of unproved properties |
157 |
38 |
157 |
2,349 |
|||||||||||
| Stock-based compensation expense |
4,358 |
7,047 |
9,813 |
13,915 |
|||||||||||
| Net derivative (gain) loss |
(55,189) |
163,351 |
(169,963) |
149,123 |
|||||||||||
| Derivative settlement gain |
16,303 |
101,710 |
16,310 |
248,738 |
|||||||||||
| Net (gain) loss on divestiture activity |
167,133 |
(50,046) |
129,670 |
18,975 |
|||||||||||
| (Gain) loss on extinguishment of debt |
— |
— |
35 |
(15,722) |
|||||||||||
| Other |
(151) |
3,125 |
4,835 |
3,557 |
|||||||||||
| Adjusted EBITDAX (Non-GAAP) |
$ |
154,088 |
$ |
217,098 |
$ |
326,274 |
$ |
399,408 |
|||||||
| Interest expense |
(44,595) |
(34,035) |
(91,548) |
(65,123) |
|||||||||||
| Other non-operating income, net |
1,265 |
5 |
1,600 |
11 |
|||||||||||
| Income tax benefit |
71,061 |
95,898 |
26,555 |
290,773 |
|||||||||||
| Exploration(2) |
(12,077) |
(11,402) |
(22,647) |
(25,013) |
|||||||||||
| Amortization of debt discount and deferred financing costs |
3,733 |
2,850 |
8,679 |
1,930 |
|||||||||||
| Deferred income taxes |
(64,015) |
(95,975) |
(30,790) |
(291,014) |
|||||||||||
| Plugging and abandonment |
(418) |
(2,112) |
(1,609) |
(2,716) |
|||||||||||
| Other, net |
(2,149) |
543 |
(2,581) |
(1,040) |
|||||||||||
| Changes in current assets and liabilities |
256 |
(34,273) |
28,182 |
(50,343) |
|||||||||||
| Net cash provided by operating activities (GAAP) |
$ |
107,149 |
$ |
138,597 |
$ |
242,115 |
$ |
256,873 |
|||||||
| (1) Adjusted EBITDAX represents net income (loss) before interest expense, other non-operating income and expense, income taxes, depletion, depreciation, amortization and asset retirement obligation liability accretion expense, exploration expense, property impairments, non-cash stock-based compensation expense, derivative gains and losses net of settlements, change in the Net Profits Plan liability, gains and losses on divestitures, gains and losses on extinguishment of debt, and materials inventory impairments and losses on sale. Adjusted EBITDAX excludes certain items that we believe affect the comparability of operating results and can exclude items that are generally one-time in nature or whose timing and/or amount cannot be reasonably estimated. Adjusted EBITDAX is a non-GAAP measure that we present because we believe it provides useful additional information to investors and analysts, as a performance measure, for analysis of our ability to internally generate funds for exploration, development, acquisitions, and to service debt. We are also subject to financial covenants under our Credit Agreement based on adjusted EBITDAX ratios. In addition, adjusted EBITDAX is widely used by professional research analysts and others in the valuation, comparison, and investment recommendations of companies in the oil and gas exploration and production industry, and many investors use the published research of industry research analysts in making investment decisions. Adjusted EBITDAX should not be considered in isolation or as a substitute for net income (loss), income (loss) from operations, net cash provided by operating activities, or profitability or liquidity measures prepared under GAAP. Because adjusted EBITDAX excludes some, but not all items that affect net income (loss) and may vary among companies, the adjusted EBITDAX amounts presented may not be comparable to similar metrics of other companies. Our credit facility provides a material source of liquidity for us. Under the terms of our Credit Agreement, if we failed to comply with the covenants that establish a maximum permitted ratio of senior secured debt to adjusted EBITDAX and a minimum permitted ratio of adjusted EBITDAX to interest, we would be in default, an event that would prevent us from borrowing under our credit facility and would therefore materially limit our sources of liquidity. In addition, if we are in default under our credit facility and are unable to obtain a waiver of that default from our lenders, lenders under that facility and under the indentures governing our outstanding Senior Notes and Senior Convertible Notes would be entitled to exercise all of their remedies for default. |
|||||||||||||||
| (2) Stock-based compensation expense is a component of exploration expense and general and administrative expense on the accompanying statements of operations. Therefore, the exploration line items shown in the reconciliation above will vary from the amount shown on the Company's condensed consolidated statements of operations for the component of stock-based compensation expense recorded to exploration expense.
|
| SM ENERGY COMPANY |
|||||||||||||||
| FINANCIAL HIGHLIGHTS (UNAUDITED) |
|||||||||||||||
| June 30, 2017 |
|||||||||||||||
| Adjusted Net Loss (Non-GAAP) |
|||||||||||||||
| (in thousands, except per share data) |
|||||||||||||||
| For the Three Months Ended |
For the Six Months Ended |
||||||||||||||
| 2017 |
2016 |
2017 |
2016 |
||||||||||||
| Net loss (GAAP) |
$ |
(119,907) |
$ |
(168,681) |
$ |
(45,473) |
$ |
(515,891) |
|||||||
| Net derivative (gain) loss |
(55,189) |
163,351 |
(169,963) |
149,123 |
|||||||||||
| Derivative settlement gain |
16,303 |
101,710 |
16,310 |
248,738 |
|||||||||||
| Net (gain) loss on divestiture activity |
167,133 |
(50,046) |
129,670 |
18,975 |
|||||||||||
| Impairment of proved properties |
3,806 |
— |
3,806 |
269,785 |
|||||||||||
| Abandonment and impairment of unproved properties |
157 |
38 |
157 |
2,349 |
|||||||||||
| (Gain) loss on extinguishment of debt |
— |
— |
35 |
(15,722) |
|||||||||||
| Other, net(2) |
(151) |
3,091 |
4,835 |
2,583 |
|||||||||||
| Tax effect of adjustments(1) |
(47,673) |
(79,622) |
5,469 |
(246,678) |
|||||||||||
| Adjusted net loss (Non-GAAP)(3) |
$ |
(35,521) |
$ |
(30,159) |
$ |
(55,154) |
$ |
(86,738) |
|||||||
| Diluted net loss per common share (GAAP) |
$ |
(1.08) |
$ |
(2.48) |
$ |
(0.41) |
$ |
(7.58) |
|||||||
| Net derivative gain |
(0.50) |
2.40 |
(1.53) |
2.19 |
|||||||||||
| Derivative settlement gain |
0.15 |
1.49 |
0.15 |
3.65 |
|||||||||||
| Net (gain) loss on divestiture activity |
1.50 |
(0.73) |
1.17 |
0.28 |
|||||||||||
| Impairment of proved properties |
0.03 |
— |
0.03 |
3.96 |
|||||||||||
| Abandonment and impairment of unproved properties |
— |
— |
— |
0.03 |
|||||||||||
| (Gain) loss on extinguishment of debt |
— |
— |
— |
(0.23) |
|||||||||||
| Other, net(2) |
— |
0.05 |
0.04 |
0.04 |
|||||||||||
| Tax effect of adjustments(1) |
(0.42) |
(1.17) |
0.05 |
(3.61) |
|||||||||||
| Adjusted net loss per diluted common share (Non-GAAP)(4) |
$ |
(0.32) |
$ |
(0.44) |
$ |
(0.50) |
$ |
(1.27) |
|||||||
| Basic weighted-average common shares outstanding (GAAP) |
111,277 |
68,102 |
111,274 |
68,090 |
|||||||||||
| (1) The tax effect of adjustments is calculated using a tax rate of 36.1% for the three-month and six-month periods ended June 30, 2017, and a tax rate of 36.5% for the three-month and six-month periods ended June 30, 2016. These rates approximate the Company's statutory tax rate for the respective periods, as adjusted for ordinary permanent differences. |
|||||||||||||||
| (2) For the three-month and six-month periods ended June 30, 2017, the adjustment is related to the change in Net Profits Plan liability. Additionally, for the six-month period ended June 30, 2017, an adjustment related to materials inventory loss is included. For the three-month and six-month periods ended June 30, 2016, the adjustment relates to the change in Net Profits Plan liability, impairment of materials inventory, and an adjustment relating to claims on royalties on certain Federal and Indian leases. These items are included in other operating expenses on the Company's condensed consolidated statements of operations. |
|||||||||||||||
| (3) Adjusted net loss excludes certain items that the Company believes affect the comparability of operating results. Items excluded generally are non-recurring items or are items whose timing and/or amount cannot be reasonably estimated. These items include non-cash and other adjustments, such as derivative gains and losses net of settlements, impairments, net (gain) loss on divestiture activity, materials inventory loss, and gains or losses on extinguishment of debt. The non-GAAP measure of adjusted net income (loss) is presented because management believes it provides useful additional information to investors for analysis of SM Energy's fundamental business on a recurring basis. In addition, management believes that adjusted net income (loss) is widely used by professional research analysts and others in the valuation, comparison, and investment recommendations of companies in the oil and gas exploration and production industry, and many investors use the published research of industry research analysts in making investment decisions. Adjusted net income (loss) should not be considered in isolation or as a substitute for net income (loss), income (loss) from operations, cash provided by operating activities, or other income, profitability, cash flow, or liquidity measures prepared under GAAP. Since adjusted net income (loss) excludes some, but not all, items that affect net income (loss) and may vary among companies, the adjusted net income (loss) amounts presented may not be comparable to similarly titled measures of other companies. |
|||||||||||||||
| (4) For periods where the Company reports adjusted net loss, basic weighted-average common shares outstanding are used in the calculation of adjusted net loss per diluted common share. |
| SM ENERGY COMPANY |
||||||||
| FINANCIAL HIGHLIGHTS (UNAUDITED) |
||||||||
| June 30, 2017 |
||||||||
| Total Capital Spend Reconciliation |
||||||||
| (in millions) |
||||||||
| Reconciliation of costs incurred in oil & gas activities (GAAP) to total capital spend (Non-GAAP)(1)(3) |
For the Three Months Ended |
For the Six Months Ended |
||||||
| 2017 |
2017 |
|||||||
| Costs incurred in oil and gas activities (GAAP): |
$ |
258.0 |
$ |
515.0 |
||||
| Less: |
||||||||
| Asset retirement obligation |
(0.5) |
(1.4) |
||||||
| Capitalized interest |
(2.9) |
(5.1) |
||||||
| Proved property acquisitions(2) |
0.8 |
(1.4) |
||||||
| Unproved property acquisitions |
(16.5) |
(75.6) |
||||||
| Other |
(1.6) |
(1.3) |
||||||
| Total capital spend (Non-GAAP): |
$ |
237.3 |
$ |
430.2 |
||||
| (1) The non-GAAP measure of total capital spend is presented because management believes it provides useful information to investors for analysis of SM Energy's fundamental business on a recurring basis. In addition, management believes that total capital spend is widely used by professional research analysts and others in the valuation, comparison, and investment recommendations of companies in the oil and gas exploration and production industry, and many investors use the published research of industry research analysts in making investment decisions. Total capital spend should not be considered in isolation or as a substitute for Costs Incurred or other capital spending measures prepared under GAAP. The total capital spend amounts presented may not be comparable to similarly titled measures of other companies. |
||||||||
| (2) Includes approximately $76,000 and $887,000 of ARO associated with proved property acquisitions for the three and six months ended June 30, 2017, respectively. |
||||||||
| (3) The Company completed several primarily non-monetary acreage trades in the Midland Basin during the first half of 2017 totaling $279.8 million of value attributed to the properties surrendered. This non-monetary consideration is not reflected in the costs incurred or capital spend amounts presented above. |
||||||||
SOURCE SM Energy Company
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