þ
|
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
|
¨
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TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
|
Delaware
|
|
26-1075808
|
(State or other jurisdiction of
incorporation or organization)
|
|
(I.R.S. Employer
Identification No.)
|
|
|
|
1201 Lake Robbins Drive
The Woodlands, Texas
|
|
77380
|
(Address of principal executive offices)
|
|
(Zip Code)
|
Large accelerated filer
þ
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Accelerated filer
¨
|
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Non-accelerated filer
¨
|
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Smaller reporting company
¨
|
|
Emerging growth company
¨
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PAGE
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PART I
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Item 1.
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Item 2.
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Item 3.
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Item 4.
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PART II
|
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Item 1.
|
||
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Item 1A.
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Item 2.
|
||
|
Item 6.
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
thousands except per-unit amounts
|
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
Revenues and other – affiliates
|
|
|
|
|
|
|
|
|
||||||||
Service revenues – fee based
|
|
$
|
204,090
|
|
|
$
|
157,303
|
|
|
$
|
582,579
|
|
|
$
|
484,601
|
|
Service revenues – product based
|
|
701
|
|
|
—
|
|
|
1,228
|
|
|
—
|
|
||||
Product sales
|
|
69,723
|
|
|
185,002
|
|
|
182,372
|
|
|
489,172
|
|
||||
Other
|
|
—
|
|
|
8,822
|
|
|
—
|
|
|
8,822
|
|
||||
Total revenues and other – affiliates
|
|
274,514
|
|
|
351,127
|
|
|
766,179
|
|
|
982,595
|
|
||||
Revenues and other – third parties
|
|
|
|
|
|
|
|
|
||||||||
Service revenues – fee based
|
|
205,016
|
|
|
148,884
|
|
|
563,520
|
|
|
428,835
|
|
||||
Service revenues – product based
|
|
22,034
|
|
|
—
|
|
|
66,205
|
|
|
—
|
|
||||
Product sales
|
|
5,427
|
|
|
74,139
|
|
|
35,366
|
|
|
201,318
|
|
||||
Other
|
|
771
|
|
|
545
|
|
|
1,213
|
|
|
3,590
|
|
||||
Total revenues and other – third parties
|
|
233,248
|
|
|
223,568
|
|
|
666,304
|
|
|
633,743
|
|
||||
Total revenues and other
|
|
507,762
|
|
|
574,695
|
|
|
1,432,483
|
|
|
1,616,338
|
|
||||
Equity income, net – affiliates
|
|
43,110
|
|
|
21,519
|
|
|
102,752
|
|
|
62,708
|
|
||||
Operating expenses
|
|
|
|
|
|
|
|
|
||||||||
Cost of product
(1)
|
|
105,966
|
|
|
239,223
|
|
|
303,518
|
|
|
631,859
|
|
||||
Operation and maintenance
(1)
|
|
111,359
|
|
|
79,536
|
|
|
300,266
|
|
|
229,444
|
|
||||
General and administrative
(1)
|
|
14,467
|
|
|
12,158
|
|
|
42,634
|
|
|
35,402
|
|
||||
Property and other taxes
|
|
10,954
|
|
|
11,215
|
|
|
35,090
|
|
|
35,433
|
|
||||
Depreciation and amortization
|
|
82,553
|
|
|
72,539
|
|
|
238,187
|
|
|
216,272
|
|
||||
Impairments
|
|
25,317
|
|
|
2,159
|
|
|
152,708
|
|
|
170,079
|
|
||||
Total operating expenses
|
|
350,616
|
|
|
416,830
|
|
|
1,072,403
|
|
|
1,318,489
|
|
||||
Gain (loss) on divestiture and other, net
(2)
|
|
65
|
|
|
72
|
|
|
351
|
|
|
135,017
|
|
||||
Proceeds from business interruption insurance claims
|
|
—
|
|
|
—
|
|
|
—
|
|
|
29,882
|
|
||||
Operating income (loss)
|
|
200,321
|
|
|
179,456
|
|
|
463,183
|
|
|
525,456
|
|
||||
Interest income – affiliates
|
|
4,225
|
|
|
4,225
|
|
|
12,675
|
|
|
12,675
|
|
||||
Interest expense
|
|
(47,991
|
)
|
|
(35,544
|
)
|
|
(131,663
|
)
|
|
(106,794
|
)
|
||||
Other income (expense), net
|
|
598
|
|
|
286
|
|
|
2,609
|
|
|
969
|
|
||||
Income (loss) before income taxes
|
|
157,153
|
|
|
148,423
|
|
|
346,804
|
|
|
432,306
|
|
||||
Income tax (benefit) expense
|
|
1,517
|
|
|
510
|
|
|
3,301
|
|
|
4,905
|
|
||||
Net income (loss)
|
|
155,636
|
|
|
147,913
|
|
|
343,503
|
|
|
427,401
|
|
||||
Net income attributable to noncontrolling interest
|
|
990
|
|
|
4,407
|
|
|
6,786
|
|
|
8,555
|
|
||||
Net income (loss) attributable to Western Gas Partners, LP
|
|
$
|
154,646
|
|
|
$
|
143,506
|
|
|
$
|
336,717
|
|
|
$
|
418,846
|
|
Limited partners’ interest in net income (loss):
|
|
|
|
|
|
|
|
|
||||||||
Net income (loss) attributable to Western Gas Partners, LP
|
|
$
|
154,646
|
|
|
$
|
143,506
|
|
|
$
|
336,717
|
|
|
$
|
418,846
|
|
Series A Preferred units interest in net (income) loss
(3)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(42,373
|
)
|
||||
General partner interest in net (income) loss
(3)
|
|
(88,551
|
)
|
|
(78,376
|
)
|
|
(256,166
|
)
|
|
(222,903
|
)
|
||||
Common and Class C limited partners’ interest in net income (loss)
(3)
|
|
66,095
|
|
|
65,130
|
|
|
80,551
|
|
|
153,570
|
|
||||
Net income (loss) per common unit – basic and diluted
(3)
|
|
$
|
0.39
|
|
|
$
|
0.38
|
|
|
$
|
0.46
|
|
|
$
|
0.91
|
|
(1)
|
Cost of product includes product purchases from affiliates (as defined in
Note 1
) of
$47.0 million
and
$131.4 million
for the
three and nine months ended September 30, 2018
, respectively, and
$22.9 million
and
$60.5 million
for the
three and nine months ended September 30, 2017
, respectively. Operation and maintenance includes charges from affiliates of
$25.1 million
and
$68.8 million
for the
three and nine months ended September 30, 2018
, respectively, and
$18.1 million
and
$53.7 million
for the
three and nine months ended September 30, 2017
, respectively. General and administrative includes charges from affiliates of
$11.6 million
and
$34.4 million
for the
three and nine months ended September 30, 2018
, respectively, and
$10.1 million
and
$29.0 million
for the
three and nine months ended September 30, 2017
, respectively. See
Note 6
.
|
(2)
|
Includes losses related to an incident at the DBM complex for the
nine months ended September 30, 2017
. See
Note 1
.
|
(3)
|
See
Note 5
for the calculation of net income (loss) per common unit.
|
thousands except number of units
|
|
September 30,
2018 |
|
December 31,
2017 |
||||
ASSETS
|
|
|
|
|
||||
Current assets
|
|
|
|
|
||||
Cash and cash equivalents
|
|
$
|
130,668
|
|
|
$
|
78,814
|
|
Accounts receivable, net
(1)
|
|
224,986
|
|
|
160,432
|
|
||
Other current assets
(2)
|
|
25,970
|
|
|
14,816
|
|
||
Total current assets
|
|
381,624
|
|
|
254,062
|
|
||
Note receivable – Anadarko
|
|
260,000
|
|
|
260,000
|
|
||
Property, plant and equipment
|
|
|
|
|
||||
Cost
|
|
8,912,755
|
|
|
7,864,535
|
|
||
Less accumulated depreciation
|
|
2,494,121
|
|
|
2,133,644
|
|
||
Net property, plant and equipment
|
|
6,418,634
|
|
|
5,730,891
|
|
||
Goodwill
|
|
416,160
|
|
|
416,160
|
|
||
Other intangible assets
|
|
753,947
|
|
|
775,269
|
|
||
Equity investments
|
|
786,876
|
|
|
566,211
|
|
||
Other assets
|
|
14,057
|
|
|
11,757
|
|
||
Total assets
|
|
$
|
9,031,298
|
|
|
$
|
8,014,350
|
|
LIABILITIES, EQUITY AND PARTNERS’ CAPITAL
|
|
|
|
|
||||
Current liabilities
|
|
|
|
|
||||
Accounts and imbalance payables
|
|
$
|
360,651
|
|
|
$
|
349,801
|
|
Accrued ad valorem taxes
|
|
37,123
|
|
|
26,633
|
|
||
Accrued liabilities
(3)
|
|
114,286
|
|
|
47,899
|
|
||
Total current liabilities
|
|
512,060
|
|
|
424,333
|
|
||
Long-term liabilities
|
|
|
|
|
||||
Long-term debt
|
|
4,566,464
|
|
|
3,464,712
|
|
||
Deferred income taxes
|
|
10,285
|
|
|
7,409
|
|
||
Asset retirement obligations
|
|
157,933
|
|
|
143,394
|
|
||
Other liabilities
(4)
|
|
141,957
|
|
|
3,491
|
|
||
Total long-term liabilities
|
|
4,876,639
|
|
|
3,619,006
|
|
||
Total liabilities
|
|
5,388,699
|
|
|
4,043,339
|
|
||
Equity and partners’ capital
|
|
|
|
|
||||
Common units (152,609,285 and 152,602,105 units issued and outstanding at September 30, 2018, and December 31, 2017, respectively)
|
|
2,595,719
|
|
|
2,950,010
|
|
||
Class C units (14,045,429 and 13,243,883 units issued and outstanding at September 30, 2018, and December 31, 2017, respectively)
(5)
|
|
787,420
|
|
|
780,040
|
|
||
General partner units (2,583,068 units issued and outstanding at September 30, 2018, and December 31, 2017)
|
|
199,433
|
|
|
179,232
|
|
||
Total partners’ capital
|
|
3,582,572
|
|
|
3,909,282
|
|
||
Noncontrolling interest
|
|
60,027
|
|
|
61,729
|
|
||
Total equity and partners’ capital
|
|
3,642,599
|
|
|
3,971,011
|
|
||
Total liabilities, equity and partners’ capital
|
|
$
|
9,031,298
|
|
|
$
|
8,014,350
|
|
(1)
|
Accounts receivable, net includes amounts receivable from affiliates (as defined in
Note 1
) of
$59.2 million
and
$36.3 million
as of
September 30, 2018
, and December 31,
2017
, respectively.
|
(2)
|
Other current assets includes affiliate amounts of
$1.4 million
and
zero
as of
September 30, 2018
, and December 31,
2017
, respectively.
|
(3)
|
Accrued liabilities includes affiliate amounts of
$2.3 million
and
$0.2 million
as of
September 30, 2018
, and December 31,
2017
, respectively.
|
(4)
|
Other liabilities includes affiliate amounts of
$50.2 million
and
$0.7 million
as of
September 30, 2018
, and December 31,
2017
, respectively.
|
(5)
|
The Class C units will convert into common units on a
one
-for-one basis on March 1, 2020, unless the Partnership elects to convert such units earlier or Anadarko extends the conversion date. See
Note 5
.
|
|
|
Partners’ Capital
|
|
|
|
|
||||||||||||||
thousands
|
|
Common
Units
|
|
Class C
Units
|
|
General
Partner
Units
|
|
Noncontrolling
Interest
|
|
Total
|
||||||||||
Balance at December 31, 2017
|
|
$
|
2,950,010
|
|
|
$
|
780,040
|
|
|
$
|
179,232
|
|
|
$
|
61,729
|
|
|
$
|
3,971,011
|
|
Cumulative effect of accounting change
(1)
|
|
(41,108
|
)
|
|
(3,533
|
)
|
|
(696
|
)
|
|
958
|
|
|
(44,379
|
)
|
|||||
Net income (loss)
|
|
72,072
|
|
|
8,479
|
|
|
256,166
|
|
|
6,786
|
|
|
343,503
|
|
|||||
Above-market component of swap agreements with Anadarko
(2)
|
|
40,722
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
40,722
|
|
|||||
Amortization of beneficial conversion feature of Class C units
|
|
(2,434
|
)
|
|
2,434
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|||||
Distributions to noncontrolling interest owner
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(9,446
|
)
|
|
(9,446
|
)
|
|||||
Distributions to unitholders
|
|
(428,056
|
)
|
|
—
|
|
|
(235,354
|
)
|
|
—
|
|
|
(663,410
|
)
|
|||||
Contributions of equity-based compensation from Anadarko
|
|
4,210
|
|
|
—
|
|
|
85
|
|
|
—
|
|
|
4,295
|
|
|||||
Other
|
|
303
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
303
|
|
|||||
Balance at September 30, 2018
|
|
$
|
2,595,719
|
|
|
$
|
787,420
|
|
|
$
|
199,433
|
|
|
$
|
60,027
|
|
|
$
|
3,642,599
|
|
(1)
|
See
Note 1
.
|
(2)
|
See
Note 6
.
|
|
|
Nine Months Ended
September 30, |
||||||
thousands
|
|
2018
|
|
2017
|
||||
Cash flows from operating activities
|
|
|
|
|
||||
Net income (loss)
|
|
$
|
343,503
|
|
|
$
|
427,401
|
|
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
|
|
|
|
|
||||
Depreciation and amortization
|
|
238,187
|
|
|
216,272
|
|
||
Impairments
|
|
152,708
|
|
|
170,079
|
|
||
Non-cash equity-based compensation expense
|
|
4,620
|
|
|
3,573
|
|
||
Deferred income taxes
|
|
3,054
|
|
|
3,882
|
|
||
Accretion and amortization of long-term obligations, net
|
|
3,883
|
|
|
3,194
|
|
||
Equity income, net – affiliates
|
|
(102,752
|
)
|
|
(62,708
|
)
|
||
Distributions from equity investment earnings – affiliates
|
|
93,827
|
|
|
64,313
|
|
||
(Gain) loss on divestiture and other, net
(1)
|
|
(351
|
)
|
|
(135,017
|
)
|
||
Lower of cost or market inventory adjustments
|
|
184
|
|
|
140
|
|
||
Changes in assets and liabilities:
|
|
|
|
|
||||
(Increase) decrease in accounts receivable, net
|
|
(64,544
|
)
|
|
(46,972
|
)
|
||
Increase (decrease) in accounts and imbalance payables and accrued liabilities, net
|
|
55,354
|
|
|
4,007
|
|
||
Change in other items, net
|
|
24,049
|
|
|
(3,065
|
)
|
||
Net cash provided by operating activities
|
|
751,722
|
|
|
645,099
|
|
||
Cash flows from investing activities
|
|
|
|
|
||||
Capital expenditures
|
|
(949,022
|
)
|
|
(419,193
|
)
|
||
Contributions in aid of construction costs from affiliates
|
|
—
|
|
|
1,386
|
|
||
Acquisitions from affiliates
|
|
(254
|
)
|
|
(3,910
|
)
|
||
Acquisitions from third parties
|
|
(161,858
|
)
|
|
(155,298
|
)
|
||
Investments in equity affiliates
|
|
(67,979
|
)
|
|
(384
|
)
|
||
Distributions from equity investments in excess of cumulative earnings – affiliates
|
|
18,097
|
|
|
16,255
|
|
||
Proceeds from the sale of assets to third parties
|
|
332
|
|
|
23,370
|
|
||
Proceeds from property insurance claims
|
|
—
|
|
|
22,977
|
|
||
Net cash used in investing activities
|
|
(1,160,684
|
)
|
|
(514,797
|
)
|
||
Cash flows from financing activities
|
|
|
|
|
||||
Borrowings, net of debt issuance costs
|
|
2,135,637
|
|
|
249,989
|
|
||
Repayments of debt
|
|
(1,040,000
|
)
|
|
—
|
|
||
Settlement of the Deferred purchase price obligation – Anadarko
(2)
|
|
—
|
|
|
(37,346
|
)
|
||
Increase (decrease) in outstanding checks
|
|
(2,687
|
)
|
|
3,310
|
|
||
Proceeds from the issuance of common units, net of offering expenses
|
|
—
|
|
|
(183
|
)
|
||
Distributions to unitholders
(3)
|
|
(663,410
|
)
|
|
(589,262
|
)
|
||
Distributions to noncontrolling interest owner
|
|
(9,446
|
)
|
|
(9,049
|
)
|
||
Net contributions from (distributions to) Anadarko
|
|
—
|
|
|
30
|
|
||
Above-market component of swap agreements with Anadarko
(3)
|
|
40,722
|
|
|
46,719
|
|
||
Net cash provided by (used in) financing activities
|
|
460,816
|
|
|
(335,792
|
)
|
||
Net increase (decrease) in cash and cash equivalents
|
|
51,854
|
|
|
(205,490
|
)
|
||
Cash and cash equivalents at beginning of period
|
|
78,814
|
|
|
357,925
|
|
||
Cash and cash equivalents at end of period
|
|
$
|
130,668
|
|
|
$
|
152,435
|
|
Supplemental disclosures
|
|
|
|
|
||||
Accretion expense and revisions to the Deferred purchase price obligation – Anadarko
|
|
$
|
—
|
|
|
$
|
(4,094
|
)
|
Net distributions to (contributions from) Anadarko of other assets
|
|
—
|
|
|
(1,373
|
)
|
||
Interest paid, net of capitalized interest
|
|
113,866
|
|
|
97,811
|
|
||
Taxes paid (reimbursements received)
|
|
(87
|
)
|
|
189
|
|
||
Accrued capital expenditures
|
|
178,694
|
|
|
165,732
|
|
||
Fair value of properties and equipment from non-cash third party transactions
(2)
|
|
—
|
|
|
551,453
|
|
(1)
|
Includes losses related to an incident at the DBM complex for the
nine months ended September 30, 2017
. See
Note 1
.
|
(2)
|
See
Note 3
.
|
(3)
|
See
Note 6
.
|
|
|
Owned and
Operated
|
|
Operated
Interests
|
|
Non-Operated
Interests
|
|
Equity
Interests
|
||||
Gathering systems
(1)
|
|
12
|
|
|
3
|
|
|
3
|
|
|
2
|
|
Treating facilities
|
|
19
|
|
|
3
|
|
|
—
|
|
|
3
|
|
Natural gas processing plants/trains
|
|
20
|
|
|
4
|
|
|
—
|
|
|
2
|
|
NGL pipelines
|
|
2
|
|
|
—
|
|
|
—
|
|
|
3
|
|
Natural gas pipelines
|
|
5
|
|
|
—
|
|
|
—
|
|
|
—
|
|
Oil pipelines
|
|
—
|
|
|
1
|
|
|
—
|
|
|
2
|
|
(1)
|
Includes the DBM water systems.
|
|
|
Percentage Interest
|
|
Equity investments
(1)
|
|
|
|
Fort Union
|
|
14.81
|
%
|
White Cliffs
|
|
10
|
%
|
Rendezvous
|
|
22
|
%
|
Mont Belvieu JV
|
|
25
|
%
|
TEP
|
|
20
|
%
|
TEG
|
|
20
|
%
|
FRP
|
|
33.33
|
%
|
Whitethorn
|
|
20
|
%
|
Cactus II
|
|
15
|
%
|
Proportionate consolidation
(2)
|
|
|
|
Marcellus Interest systems
|
|
33.75
|
%
|
Newcastle system
|
|
50
|
%
|
Springfield system
|
|
50.1
|
%
|
Full consolidation
|
|
|
|
Chipeta
(3)
|
|
75
|
%
|
(1)
|
Investments in non-controlled entities over which the Partnership exercises significant influence are accounted for under the equity method. “Equity investment throughput” refers to the Partnership’s share of average throughput for these investments.
|
(2)
|
The Partnership proportionately consolidates its associated share of the assets, liabilities, revenues and expenses attributable to these assets.
|
(3)
|
The
25%
interest in Chipeta Processing LLC (“Chipeta”) held by a third-party member is reflected within noncontrolling interest in the consolidated financial statements.
|
•
|
Fee-based gathering / processing.
Under Topic 605, fee revenues were recognized based on the rate in effect for the month of service, even when certain fees were charged on an upfront or limited-term basis. In addition, deficiency fees were charged and recognized only when the customer did not meet the specified delivery minimums for the completed performance period. Under Topic 606, (i) revenues continue to be recognized based on the rate in effect when the fee is either the same rate per unit over the contract term or when the fee escalates and the escalation factor approximates inflation, (ii) deficiency fees are estimated and recognized during the performance period as the services are performed for the customer’s delivered volumes, and (iii) timing differences between Service revenues – fee based recognized and amounts billed to customers are recognized as contract assets or contract liabilities, as appropriate, which results in a change in the timing of revenue and changes to net income as a result of the revenue contract’s consideration provisions. In addition, under Topic 606, revenue associated with upfront or limited-term fees is recognized over the expected period of customer benefit, which is generally the life of the related properties. These revenues also include revenues earned for marketing services performed on behalf of the Partnership’s customers, and the expense associated with these marketing activities is recognized in cost of product expense, resulting in no impact to operating income.
|
•
|
Cost of service rate adjustments.
Under Topic 605, revenue was recognized based on the amounts billed to customers each period as Service revenues – fee based. Under Topic 606, fixed minimum volume commitment demand fees and variable fees that are also billed on these minimum volumes are recognized as Service revenues – fee based on a consistent per-unit rate over the term of the contract. Annual adjustments are made to the cost of service rates charged to customers, and, as a result, a cumulative catch-up revenue adjustment related to the services already provided under the contract may be recorded in future periods, with revenues for the remaining term of the contract recognized on a consistent per-unit rate. Fees received on volumes in excess of the minimum volumes are recognized as Service revenues – fee based as service is provided to the customer based on the billing rate in effect for the performance period. This revenue recognition timing does not affect billings to customers, and differences between amounts billed and revenue recognized are recorded as contract assets or liabilities, as appropriate.
|
•
|
Aid in construction.
Under Topic 605, aid in construction reimbursements were reflected as a reduction to property, plant and equipment upon receipt (and a reduction to capital expenditures). Under Topic 606, reimbursement of capital costs received from customers is reflected as a contract liability (deferred revenue) upon receipt. The contract liability is amortized to Service revenues – fee based over the expected period of customer benefit, which is generally the life of the related properties.
|
•
|
Percent-of-proceeds gathering / processing.
Under Topic 605, the Partnership recognized cost of product expense when the product was purchased from a producer to whom it provides services, and the Partnership recognized revenue when the product was sold to Anadarko or a third party. Under Topic 606, in some instances, where all or a percentage of the proceeds from the sale must be returned to the producer, the net margin from the purchase and sale transactions is presented net within Service revenues – product based because the Partnership is acting as the producer’s agent in the product sale.
|
•
|
Noncash consideration - keep-whole and percent-of-product agreements.
Under Topic 605, the Partnership recognized revenues only upon the sale of the related products. Under Topic 606, (i) Service revenues – product based is recognized for the products received as noncash consideration in exchange for the services provided, with the keep-whole noncash consideration value based on the net value of the NGLs over the replacement residue gas cost, and (ii) product sales revenue is recognized, along with cost of product expense related to the sale, when the product is sold to Anadarko or a third party. When the product is sold to Anadarko, Anadarko is acting as the Partnership’s agent in the product sale and the Partnership recognizes revenue, along with cost of product expense related to the sale, based on the Anadarko sales price to the third party, resulting in no impact to operating income.
|
•
|
Wellhead purchase / sale incorporated into gathering / processing.
Under Topic 605, the natural gas purchase cost was recognized as cost of product expense and any specified gathering or processing fees charged to the producer were recognized as revenues. Under Topic 606, the fees charged to the producer under this contract type are recognized as adjustments to the amount recognized in cost of product expense instead of revenues when such fees relate to services performed after control of the product transfers to the Partnership.
|
|
|
Three Months Ended
September 30, 2018 |
||||||||||
thousands
|
|
As Reported
|
|
Without Adoption of Topic 606
|
|
Effect of Change
Increase / (Decrease)
|
||||||
Revenues
|
|
|
|
|
|
|
||||||
Service revenues – fee based
|
|
$
|
409,106
|
|
|
$
|
396,161
|
|
|
$
|
12,945
|
|
Service revenues – product based
|
|
22,735
|
|
|
—
|
|
|
22,735
|
|
|||
Product sales
|
|
75,150
|
|
|
366,603
|
|
|
(291,453
|
)
|
|||
Expenses
|
|
|
|
|
|
|
|
|||||
Cost of product
|
|
105,966
|
|
|
353,641
|
|
|
(247,675
|
)
|
|||
Operation and maintenance
|
|
111,359
|
|
|
111,327
|
|
|
32
|
|
|||
Depreciation and amortization
|
|
82,553
|
|
|
81,824
|
|
|
729
|
|
|||
Income tax (benefit) expense
|
|
1,517
|
|
|
1,580
|
|
|
(63
|
)
|
|||
Net income attributable to noncontrolling interest
|
|
990
|
|
|
3,166
|
|
|
(2,176
|
)
|
|||
Net income (loss) attributable to Western Gas Partners, LP
|
|
154,646
|
|
|
161,266
|
|
|
(6,620
|
)
|
|
|
Nine Months Ended
September 30, 2018 |
||||||||||
thousands
|
|
As Reported
|
|
Without Adoption of Topic 606
|
|
Effect of Change
Increase / (Decrease)
|
||||||
Revenues
|
|
|
|
|
|
|
||||||
Service revenues – fee based
|
|
$
|
1,146,099
|
|
|
$
|
1,096,708
|
|
|
$
|
49,391
|
|
Service revenues – product based
|
|
67,433
|
|
|
—
|
|
|
67,433
|
|
|||
Product sales
|
|
217,738
|
|
|
978,127
|
|
|
(760,389
|
)
|
|||
Expenses
|
|
|
|
|
|
|
|
|||||
Cost of product
|
|
303,518
|
|
|
940,936
|
|
|
(637,418
|
)
|
|||
Operation and maintenance
|
|
300,266
|
|
|
300,098
|
|
|
168
|
|
|||
Depreciation and amortization
|
|
238,187
|
|
|
236,102
|
|
|
2,085
|
|
|||
Impairments
|
|
152,708
|
|
|
152,663
|
|
|
45
|
|
|||
Income tax (benefit) expense
|
|
3,301
|
|
|
3,361
|
|
|
(60
|
)
|
|||
Net income attributable to noncontrolling interest
|
|
6,786
|
|
|
7,718
|
|
|
(932
|
)
|
|||
Net income (loss) attributable to Western Gas Partners, LP
|
|
336,717
|
|
|
344,170
|
|
|
(7,453
|
)
|
|
|
September 30, 2018
|
||||||||||
thousands
|
|
As Reported
|
|
Without Adoption of Topic 606
|
|
Effect of Change
Increase / (Decrease)
|
||||||
Assets
|
|
|
|
|
|
|
||||||
Other current assets
|
|
$
|
25,970
|
|
|
$
|
23,222
|
|
|
$
|
2,748
|
|
Net property, plant and equipment
|
|
6,418,634
|
|
|
6,320,225
|
|
|
98,409
|
|
|||
Other assets
|
|
14,057
|
|
|
13,894
|
|
|
163
|
|
|||
Liabilities
|
|
|
|
|
|
|
|
|||||
Accrued liabilities
|
|
114,286
|
|
|
106,592
|
|
|
7,694
|
|
|||
Deferred income taxes
|
|
10,285
|
|
|
10,519
|
|
|
(234
|
)
|
|||
Other liabilities
|
|
141,957
|
|
|
2,781
|
|
|
139,176
|
|
|||
Equity and partners’ capital
|
|
|
|
|
|
|
|
|||||
Total equity and partners’ capital
|
|
3,642,599
|
|
|
3,687,915
|
|
|
(45,316
|
)
|
thousands
|
|
Three Months Ended
September 30, 2018 |
|
Nine Months Ended
September 30, 2018 |
||||
Revenue from customers
|
|
|
|
|
||||
Service revenues – fee based
|
|
$
|
409,106
|
|
|
$
|
1,146,099
|
|
Service revenues – product based
|
|
22,735
|
|
|
67,433
|
|
||
Product sales
|
|
78,887
|
|
|
224,089
|
|
||
Total revenue from customers
|
|
510,728
|
|
|
1,437,621
|
|
||
Revenue from other than customers
|
|
|
|
|
||||
Net gains (losses) on commodity price swap agreements
|
|
(3,737
|
)
|
|
(6,351
|
)
|
||
Other
|
|
771
|
|
|
1,213
|
|
||
Total revenues and other
|
|
$
|
507,762
|
|
|
$
|
1,432,483
|
|
thousands
|
|
|
||
Balance at December 31, 2017
|
|
$
|
—
|
|
Cumulative effect of adopting Topic 606
|
|
5,129
|
|
|
Amounts transferred to Accounts receivable, net from contract assets recognized in the adoption effect
(1)
|
|
(4,358
|
)
|
|
Additional estimated revenues recognized
(2)
|
|
2,140
|
|
|
Balance at September 30, 2018
|
|
$
|
2,911
|
|
|
|
|
||
Contract assets at September 30, 2018
|
|
|
||
Other current assets
|
|
$
|
2,748
|
|
Other assets
|
|
163
|
|
|
Total contract assets from contracts with customers
|
|
$
|
2,911
|
|
(1)
|
Includes
$(1.7) million
for the three months ended
September 30, 2018
.
|
(2)
|
Includes
$(5.0) million
for the three months ended
September 30, 2018
.
|
thousands
|
|
|
||
Balance at December 31, 2017
|
|
$
|
—
|
|
Cumulative effect of adopting Topic 606
|
|
120,717
|
|
|
Cash received or receivable, excluding revenues recognized during the period
(1)
|
|
37,340
|
|
|
Revenues recognized during the period that were included in the adoption effect
(2)
|
|
(10,850
|
)
|
|
Balance at September 30, 2018
|
|
$
|
147,207
|
|
|
|
|
||
Contract liabilities at September 30, 2018
|
|
|
||
Accrued liabilities
|
|
$
|
8,031
|
|
Other liabilities
|
|
139,176
|
|
|
Total contract liabilities from contracts with customers
|
|
$
|
147,207
|
|
(1)
|
Includes
$(3.7) million
for the three months ended
September 30, 2018
.
|
(2)
|
Includes
$(8.8) million
for the three months ended
September 30, 2018
, of which
$(7.5) million
was from a performance obligation satisfied in a previous period related to the arbitration against SWEPI LP (see
Note 11
).
|
thousands
|
|
|
||
Remainder of 2018
|
|
$
|
124,395
|
|
2019
|
|
480,211
|
|
|
2020
|
|
545,223
|
|
|
2021
|
|
524,810
|
|
|
2022
|
|
528,900
|
|
|
Thereafter
|
|
2,191,811
|
|
|
Total
|
|
$
|
4,395,350
|
|
thousands except per-unit amounts
Quarters Ended
|
|
Total Quarterly
Distribution
per Unit
|
|
Total Quarterly
Cash Distribution
|
|
Date of
Distribution
|
|||||
2017
|
|
|
|
|
|
|
|||||
March 31
|
|
$
|
0.875
|
|
|
$
|
188,753
|
|
|
May 2017
|
|
June 30
|
|
0.890
|
|
|
207,491
|
|
|
August 2017
|
|||
September 30
|
|
0.905
|
|
|
212,038
|
|
|
November 2017
|
|||
December 31
|
|
0.920
|
|
|
216,586
|
|
|
February 2018
|
|||
2018
|
|
|
|
|
|
|
|||||
March 31
|
|
$
|
0.935
|
|
|
$
|
221,133
|
|
|
May 2018
|
|
June 30
|
|
0.950
|
|
|
225,691
|
|
|
August 2018
|
|||
September 30
(1)
|
|
0.965
|
|
|
230,239
|
|
|
November 2018
|
(1)
|
The Board of Directors declared a cash distribution to the Partnership’s unitholders for the
third quarter
of
2018
of
$0.965
per unit, or
$230.2 million
in aggregate, including incentive distributions, but excluding distributions on Class C units (see
Class C unit distributions
below). The cash distribution
is payable
on
November 13, 2018
, to unitholders of record at the close of business on
October 31, 2018
.
|
|
|
Common
Units
|
|
Class C
Units
|
|
General
Partner
Units
|
|
Total
|
||||
Balance at December 31, 2017
|
|
152,602,105
|
|
|
13,243,883
|
|
|
2,583,068
|
|
|
168,429,056
|
|
PIK Class C units
|
|
—
|
|
|
801,546
|
|
|
—
|
|
|
801,546
|
|
Long-Term Incentive Plan award vestings
|
|
7,180
|
|
|
—
|
|
|
—
|
|
|
7,180
|
|
Balance at September 30, 2018
|
|
152,609,285
|
|
|
14,045,429
|
|
|
2,583,068
|
|
|
169,237,782
|
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
thousands except per-unit amounts
|
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
Net income (loss) attributable to Western Gas Partners, LP
|
|
$
|
154,646
|
|
|
$
|
143,506
|
|
|
$
|
336,717
|
|
|
$
|
418,846
|
|
Series A Preferred units interest in net (income) loss
(1)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(42,373
|
)
|
||||
General partner interest in net (income) loss
|
|
(88,551
|
)
|
|
(78,376
|
)
|
|
(256,166
|
)
|
|
(222,903
|
)
|
||||
Common and Class C limited partners’ interest in net income (loss)
|
|
$
|
66,095
|
|
|
$
|
65,130
|
|
|
$
|
80,551
|
|
|
$
|
153,570
|
|
Net income (loss) allocable to common units
(1)
|
|
$
|
59,732
|
|
|
$
|
57,448
|
|
|
$
|
69,638
|
|
|
$
|
132,545
|
|
Net income (loss) allocable to Class C units
(1)
|
|
6,363
|
|
|
7,682
|
|
|
10,913
|
|
|
21,025
|
|
||||
Common and Class C limited partners’ interest in net income (loss)
|
|
$
|
66,095
|
|
|
$
|
65,130
|
|
|
$
|
80,551
|
|
|
$
|
153,570
|
|
Net income (loss) per unit
|
|
|
|
|
|
|
|
|
||||||||
Common units – basic and diluted
(2)
|
|
$
|
0.39
|
|
|
$
|
0.38
|
|
|
$
|
0.46
|
|
|
$
|
0.91
|
|
Weighted-average units outstanding
|
|
|
|
|
|
|
|
|
||||||||
Common units – basic and diluted
|
|
152,609
|
|
|
152,602
|
|
|
152,605
|
|
|
145,371
|
|
||||
Excluded due to anti-dilutive effect:
|
|
|
|
|
|
|
|
|
||||||||
Class C units
(2)
|
|
13,921
|
|
|
12,873
|
|
|
13,652
|
|
|
12,660
|
|
||||
Series A Preferred units assuming conversion to common units
(2)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
7,227
|
|
(1)
|
Adjusted to reflect amortization of the beneficial conversion features.
|
(2)
|
The impact of Class C units would be anti-dilutive for all periods presented and the conversion of Series A Preferred units would be anti-dilutive for the
nine months ended September 30, 2017
. On March 1, 2017,
50%
of the outstanding Series A Preferred units converted into common units on a
one
-for-one basis, and on May 2, 2017, all remaining Series A Preferred units converted into common units on a
one
-for-one basis.
|
|
|
DJ Basin Complex
|
||||||||||
per barrel except natural gas
|
|
2017 - 2018 Swap Prices
|
|
2017 Market Prices
(1)
|
|
2018 Market Prices
(1)
|
||||||
Ethane
|
|
$
|
18.41
|
|
|
$
|
5.09
|
|
|
$
|
5.41
|
|
Propane
|
|
47.08
|
|
|
18.85
|
|
|
28.72
|
|
|||
Isobutane
|
|
62.09
|
|
|
26.83
|
|
|
32.92
|
|
|||
Normal butane
|
|
54.62
|
|
|
26.20
|
|
|
32.71
|
|
|||
Natural gasoline
|
|
72.88
|
|
|
41.84
|
|
|
48.04
|
|
|||
Condensate
|
|
76.47
|
|
|
45.40
|
|
|
49.36
|
|
|||
Natural gas (per MMBtu)
|
|
5.96
|
|
|
3.05
|
|
|
2.21
|
|
|
|
MGR Assets
|
||||||||||
per barrel except natural gas
|
|
2017 - 2018 Swap Prices
|
|
2017 Market Prices
(1)
|
|
2018 Market Prices
(1)
|
||||||
Ethane
|
|
$
|
23.11
|
|
|
$
|
4.08
|
|
|
$
|
2.52
|
|
Propane
|
|
52.90
|
|
|
19.24
|
|
|
25.83
|
|
|||
Isobutane
|
|
73.89
|
|
|
25.79
|
|
|
30.03
|
|
|||
Normal butane
|
|
64.93
|
|
|
25.16
|
|
|
29.82
|
|
|||
Natural gasoline
|
|
81.68
|
|
|
45.01
|
|
|
47.25
|
|
|||
Condensate
|
|
81.68
|
|
|
53.55
|
|
|
56.76
|
|
|||
Natural gas (per MMBtu)
|
|
4.87
|
|
|
3.05
|
|
|
2.21
|
|
(1)
|
Represents the New York Mercantile Exchange forward strip price as of December 1, 2016, and
December 20, 2017
, for the 2017 Market Prices and 2018 Market Prices, respectively, adjusted for product specification, location, basis and, in the case of NGLs, transportation and fractionation costs.
|
|
|
Nine Months Ended September 30,
|
||||||
thousands
|
|
2018
|
|
2017
|
||||
Cash consideration
|
|
$
|
254
|
|
|
$
|
3,910
|
|
Net carrying value
|
|
(254
|
)
|
|
(5,283
|
)
|
||
Partners’ capital adjustment
|
|
$
|
—
|
|
|
$
|
(1,373
|
)
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
thousands
|
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
Revenues and other
(1)
|
|
$
|
274,514
|
|
|
$
|
351,127
|
|
|
$
|
766,179
|
|
|
$
|
982,595
|
|
Equity income, net
– affiliates
(1)
|
|
43,110
|
|
|
21,519
|
|
|
102,752
|
|
|
62,708
|
|
||||
Cost of product
(1)
|
|
46,971
|
|
|
22,902
|
|
|
131,428
|
|
|
60,497
|
|
||||
Operation and maintenance
(2)
|
|
25,145
|
|
|
18,110
|
|
|
68,830
|
|
|
53,661
|
|
||||
General and administrative
(3)
|
|
11,579
|
|
|
10,140
|
|
|
34,371
|
|
|
29,040
|
|
||||
Operating expenses
|
|
83,695
|
|
|
51,152
|
|
|
234,629
|
|
|
143,198
|
|
||||
Interest income
(4)
|
|
4,225
|
|
|
4,225
|
|
|
12,675
|
|
|
12,675
|
|
||||
Interest expense
(5)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
71
|
|
||||
Settlement of the Deferred purchase price obligation – Anadarko
(6)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(37,346
|
)
|
||||
Distributions to unitholders
(7)
|
|
130,249
|
|
|
118,082
|
|
|
381,617
|
|
|
331,654
|
|
||||
Above-market component of swap agreements with Anadarko
|
|
12,601
|
|
|
18,049
|
|
|
40,722
|
|
|
46,719
|
|
(1)
|
Represents amounts earned or incurred on and subsequent to the date of the acquisition of Partnership assets, as well as amounts earned or incurred by Anadarko on a historical basis related to the Partnership assets prior to the acquisition of such assets, recognized under gathering, treating or processing agreements, and purchase and sale agreements.
|
(2)
|
Represents expenses incurred on and subsequent to the date of the acquisition of Partnership assets, as well as expenses incurred by Anadarko on a historical basis related to the Partnership assets prior to the acquisition of such assets.
|
(3)
|
Represents general and administrative expense incurred on and subsequent to the date of the acquisition of Partnership assets, as well as a management services fee for reimbursement of expenses incurred by Anadarko for periods prior to the acquisition of the Partnership assets by the Partnership. These amounts include equity-based compensation expense allocated to the Partnership by Anadarko (see
WES LTIP
and
Anadarko Incentive Plan
within this
Note 6
).
|
(4)
|
Represents interest income recognized on the note receivable from Anadarko.
|
(5)
|
Includes amounts related to the Deferred purchase price obligation - Anadarko (see
Note 3
and
Note 10
).
|
(6)
|
Represents the cash payment to Anadarko for the settlement of the Deferred purchase price obligation - Anadarko (see
Note 3
).
|
(7)
|
Represents distributions paid under the partnership agreement (see
Note 4
and
Note 5
).
|
thousands
|
|
Estimated Useful Life
|
|
September 30,
2018 |
|
December 31,
2017 |
||||
Land
|
|
n/a
|
|
$
|
4,653
|
|
|
$
|
4,450
|
|
Gathering systems and processing complexes
|
|
3 to 47 years
|
|
7,883,265
|
|
|
7,113,114
|
|
||
Pipelines and equipment
|
|
15 to 45 years
|
|
137,769
|
|
|
137,644
|
|
||
Assets under construction
|
|
n/a
|
|
856,092
|
|
|
579,501
|
|
||
Other
|
|
3 to 40 years
|
|
30,976
|
|
|
29,826
|
|
||
Total property, plant and equipment
|
|
|
|
8,912,755
|
|
|
7,864,535
|
|
||
Less accumulated depreciation
|
|
|
|
2,494,121
|
|
|
2,133,644
|
|
||
Net property, plant and equipment
|
|
|
|
$
|
6,418,634
|
|
|
$
|
5,730,891
|
|
thousands
|
|
Fort
Union |
|
White
Cliffs |
|
Rendezvous
|
|
Mont
Belvieu JV |
|
TEFR
Interests
|
|
Whitethorn
|
|
Cactus II
|
|
Total
|
||||||||||||||||
Balance at December 31, 2017
|
|
$
|
7,030
|
|
|
$
|
44,945
|
|
|
$
|
42,528
|
|
|
$
|
110,299
|
|
|
$
|
361,409
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
566,211
|
|
Acquisitions
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
150,563
|
|
|
11,295
|
|
|
161,858
|
|
||||||||
Investment earnings (loss), net of amortization
|
|
(892
|
)
|
|
8,547
|
|
|
635
|
|
|
22,916
|
|
|
47,736
|
|
|
23,810
|
|
|
—
|
|
|
102,752
|
|
||||||||
Contributions
|
|
—
|
|
|
1,278
|
|
|
—
|
|
|
—
|
|
|
24,680
|
|
|
7,069
|
|
|
34,436
|
|
|
67,463
|
|
||||||||
Capitalized interest
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
516
|
|
|
516
|
|
||||||||
Distributions
|
|
(194
|
)
|
|
(8,111
|
)
|
|
(2,091
|
)
|
|
(22,945
|
)
|
|
(43,989
|
)
|
|
(16,497
|
)
|
|
—
|
|
|
(93,827
|
)
|
||||||||
Distributions in excess of cumulative earnings
(1)
|
|
(2,889
|
)
|
|
(3,109
|
)
|
|
(2,015
|
)
|
|
(3,305
|
)
|
|
(6,779
|
)
|
|
—
|
|
|
—
|
|
|
(18,097
|
)
|
||||||||
Balance at September 30, 2018
|
|
$
|
3,055
|
|
|
$
|
43,550
|
|
|
$
|
39,057
|
|
|
$
|
106,965
|
|
|
$
|
383,057
|
|
|
$
|
164,945
|
|
|
$
|
46,247
|
|
|
$
|
786,876
|
|
(1)
|
Distributions in excess of cumulative earnings, classified as investing cash flows in the consolidated statements of cash flows, are calculated on an individual investment basis.
|
thousands
|
|
September 30, 2018
|
|
December 31, 2017
|
||||
Trade receivables, net
|
|
$
|
224,818
|
|
|
$
|
160,387
|
|
Other receivables, net
|
|
168
|
|
|
45
|
|
||
Total accounts receivable, net
|
|
$
|
224,986
|
|
|
$
|
160,432
|
|
thousands
|
|
September 30, 2018
|
|
December 31, 2017
|
||||
Natural gas liquids inventory
|
|
$
|
11,212
|
|
|
$
|
10,788
|
|
Imbalance receivables
|
|
3,829
|
|
|
1,640
|
|
||
Prepaid insurance
|
|
3,101
|
|
|
2,388
|
|
||
Contract assets
|
|
2,748
|
|
|
—
|
|
||
Other
|
|
5,080
|
|
|
—
|
|
||
Total other current assets
|
|
$
|
25,970
|
|
|
$
|
14,816
|
|
thousands
|
|
September 30, 2018
|
|
December 31, 2017
|
||||
Accrued interest expense
|
|
$
|
54,546
|
|
|
$
|
40,632
|
|
Short-term asset retirement obligations
(1)
|
|
42,872
|
|
|
2,304
|
|
||
Short-term remediation and reclamation obligations
|
|
833
|
|
|
833
|
|
||
Income taxes payable
|
|
247
|
|
|
2,495
|
|
||
Contract liabilities
|
|
8,031
|
|
|
—
|
|
||
Other
|
|
7,757
|
|
|
1,635
|
|
||
Total accrued liabilities
|
|
$
|
114,286
|
|
|
$
|
47,899
|
|
(1)
|
As of
September 30, 2018
, includes
$40.2 million
of short-term liabilities incurred during the second quarter of 2018 related to the shutdowns at the Third Creek and Kitty Draw gathering systems. See
Note 1
for further information.
|
|
|
September 30, 2018
|
|
December 31, 2017
|
||||||||||||||||||||
thousands
|
|
Principal
|
|
Carrying
Value
|
|
Fair
Value
(1)
|
|
Principal
|
|
Carrying
Value
|
|
Fair
Value
(1)
|
||||||||||||
2.600% Senior Notes due 2018
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
350,000
|
|
|
$
|
349,684
|
|
|
$
|
350,631
|
|
5.375% Senior Notes due 2021
|
|
500,000
|
|
|
496,669
|
|
|
517,160
|
|
|
500,000
|
|
|
495,815
|
|
|
530,647
|
|
||||||
4.000% Senior Notes due 2022
|
|
670,000
|
|
|
669,020
|
|
|
668,198
|
|
|
670,000
|
|
|
668,849
|
|
|
684,043
|
|
||||||
3.950% Senior Notes due 2025
|
|
500,000
|
|
|
492,596
|
|
|
478,470
|
|
|
500,000
|
|
|
491,885
|
|
|
500,885
|
|
||||||
4.650% Senior Notes due 2026
|
|
500,000
|
|
|
495,592
|
|
|
492,502
|
|
|
500,000
|
|
|
495,245
|
|
|
520,144
|
|
||||||
4.500% Senior Notes due 2028
|
|
400,000
|
|
|
394,514
|
|
|
384,964
|
|
|
—
|
|
|
—
|
|
|
—
|
|
||||||
4.750% Senior Notes due 2028
|
|
400,000
|
|
|
395,806
|
|
|
391,532
|
|
|
—
|
|
|
—
|
|
|
—
|
|
||||||
5.450% Senior Notes due 2044
|
|
600,000
|
|
|
593,319
|
|
|
565,485
|
|
|
600,000
|
|
|
593,234
|
|
|
637,827
|
|
||||||
5.300% Senior Notes due 2048
|
|
700,000
|
|
|
686,601
|
|
|
645,643
|
|
|
—
|
|
|
—
|
|
|
—
|
|
||||||
5.500% Senior Notes due 2048
|
|
350,000
|
|
|
342,347
|
|
|
331,981
|
|
|
—
|
|
|
—
|
|
|
—
|
|
||||||
RCF
|
|
—
|
|
|
—
|
|
|
—
|
|
|
370,000
|
|
|
370,000
|
|
|
370,000
|
|
||||||
Total long-term debt
|
|
$
|
4,620,000
|
|
|
$
|
4,566,464
|
|
|
$
|
4,475,935
|
|
|
$
|
3,490,000
|
|
|
$
|
3,464,712
|
|
|
$
|
3,594,177
|
|
(1)
|
Fair value is measured using the market approach and Level 2 inputs.
|
thousands
|
|
Carrying Value
|
||
Balance at December 31, 2017
|
|
$
|
3,464,712
|
|
RCF borrowings
|
|
320,000
|
|
|
Issuance of 4.500% Senior Notes due 2028
|
|
400,000
|
|
|
Issuance of 5.300% Senior Notes due 2048
|
|
700,000
|
|
|
Issuance of 4.750% Senior Notes due 2028
|
|
400,000
|
|
|
Issuance of 5.500% Senior Notes due 2048
|
|
350,000
|
|
|
Repayment of 2.600% Senior Notes due 2018
|
|
(350,000
|
)
|
|
Repayments of RCF borrowings
|
|
(690,000
|
)
|
|
Other
|
|
(28,248
|
)
|
|
Balance at September 30, 2018
|
|
$
|
4,566,464
|
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
thousands
|
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
Third parties
|
|
|
|
|
|
|
|
|
||||||||
Long-term debt
|
|
$
|
(52,935
|
)
|
|
$
|
(35,992
|
)
|
|
$
|
(142,612
|
)
|
|
$
|
(105,772
|
)
|
Amortization of debt issuance costs and commitment fees
|
|
(2,023
|
)
|
|
(1,667
|
)
|
|
(6,083
|
)
|
|
(4,942
|
)
|
||||
Capitalized interest
|
|
6,967
|
|
|
2,115
|
|
|
17,032
|
|
|
3,991
|
|
||||
Total interest expense – third parties
|
|
(47,991
|
)
|
|
(35,544
|
)
|
|
(131,663
|
)
|
|
(106,723
|
)
|
||||
Affiliates
|
|
|
|
|
|
|
|
|
||||||||
Deferred purchase price obligation – Anadarko
(1)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(71
|
)
|
||||
Total interest expense – affiliates
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(71
|
)
|
||||
Interest expense
|
|
$
|
(47,991
|
)
|
|
$
|
(35,544
|
)
|
|
$
|
(131,663
|
)
|
|
$
|
(106,794
|
)
|
(1)
|
See
Note 3
for a discussion of the Deferred purchase price obligation - Anadarko.
|
•
|
our ability to pay distributions to our unitholders;
|
•
|
our and Anadarko’s assumptions about the energy market;
|
•
|
future throughput (including Anadarko production) that is gathered or processed by or transported through our assets;
|
•
|
our operating results;
|
•
|
competitive conditions;
|
•
|
technology;
|
•
|
the availability of capital resources to fund acquisitions, capital expenditures and other contractual obligations, and our ability to access those resources from Anadarko or through the debt or equity capital markets;
|
•
|
the supply of, demand for, and price of, oil, natural gas, NGLs and related products or services;
|
•
|
our ability to mitigate exposure to the commodity price risks inherent in our percent-of-proceeds, percent-of-product and keep-whole contracts through the extension of our commodity price swap agreements with Anadarko, or otherwise;
|
•
|
weather and natural disasters;
|
•
|
inflation;
|
•
|
the availability of goods and services;
|
•
|
general economic conditions, internationally, domestically or in the jurisdictions in which we are doing business;
|
•
|
federal, state and local laws, including those that limit Anadarko and other producers’ hydraulic fracturing or other oil and natural gas operations;
|
•
|
environmental liabilities;
|
•
|
legislative or regulatory changes, including changes affecting our status as a partnership for federal income tax purposes;
|
•
|
changes in the financial or operational condition of Anadarko;
|
•
|
the creditworthiness of Anadarko or our other counterparties, including financial institutions, operating partners, and other parties;
|
•
|
changes in Anadarko’s capital program, strategy or desired areas of focus;
|
•
|
our commitments to capital projects;
|
•
|
our ability to use the RCF;
|
•
|
our ability to repay debt;
|
•
|
conflicts of interest among us, our general partner, WGP and its general partner, and affiliates, including Anadarko;
|
•
|
our ability to maintain and/or obtain rights to operate our assets on land owned by third parties;
|
•
|
our ability to acquire assets on acceptable terms from Anadarko or third parties, and Anadarko’s ability to generate an inventory of assets suitable for acquisition;
|
•
|
non-payment or non-performance of Anadarko or other significant customers, including under our gathering, processing, transportation and disposal agreements and our $260.0 million note receivable from Anadarko;
|
•
|
the timing, amount and terms of future issuances of equity and debt securities;
|
•
|
the outcome of pending and future regulatory, legislative, or other proceedings or investigations, including the investigation by the National Transportation Safety Board related to Anadarko’s operations in Colorado, and continued or additional disruptions in operations that may occur as Anadarko and we comply with regulatory orders or other state or local changes in laws or regulations in Colorado; and
|
•
|
other factors discussed below, in “Risk Factors” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Estimates” included in our
2017
Form 10-K, and in our quarterly reports on Form 10-Q, and in our other public filings and press releases.
|
|
|
Owned and
Operated
|
|
Operated
Interests
|
|
Non-Operated
Interests
|
|
Equity
Interests
|
||||
Gathering systems
(1)
|
|
12
|
|
|
3
|
|
|
3
|
|
|
2
|
|
Treating facilities
|
|
19
|
|
|
3
|
|
|
—
|
|
|
3
|
|
Natural gas processing plants/trains
|
|
20
|
|
|
4
|
|
|
—
|
|
|
2
|
|
NGL pipelines
|
|
2
|
|
|
—
|
|
|
—
|
|
|
3
|
|
Natural gas pipelines
|
|
5
|
|
|
—
|
|
|
—
|
|
|
—
|
|
Oil pipelines
|
|
—
|
|
|
1
|
|
|
—
|
|
|
2
|
|
(1)
|
Includes the DBM water systems.
|
•
|
In August 2018, we completed an offering of $400.0 million aggregate principal amount of 4.750% Senior Notes due 2028 and $350.0 million aggregate principal amount of 5.500% Senior Notes due 2048. The net proceeds were used to repay the maturing 2.600% Senior Notes due August 2018, repay amounts outstanding under the RCF and for general partnership purposes, including to fund capital expenditures. See
Liquidity and Capital Resources
within this
Item 2
for additional information.
|
•
|
In June 2018, we acquired a 20% interest in Whitethorn and a 15% interest in Cactus II, both from third parties. See
Acquisitions and Divestitures
below for additional information.
|
•
|
In March 2018, we completed an offering of $400.0 million aggregate principal amount of 4.500% Senior Notes due 2028 and $700.0 million aggregate principal amount of 5.300% Senior Notes due 2048. The net proceeds were used to repay amounts outstanding under the RCF and for general partnership purposes, including to fund capital expenditures. See
Liquidity and Capital Resources
within this
Item 2
for additional information.
|
•
|
In February 2018, we entered into the five-year $1.5 billion (expandable to $2.0 billion) RCF by amending and restating the $1.2 billion credit facility originally entered into in February 2014. See
Liquidity and Capital Resources
within this
Item 2
for additional information.
|
•
|
We raised our distribution to
$0.965
per unit for the
third
quarter of
2018
, representing a
2%
increase
over the distribution for the
second
quarter of
2018
and a
7%
increase
over the distribution for the
third
quarter of
2017
.
|
•
|
Throughput attributable to Western Gas Partners, LP for natural gas assets totaled
3,850
MMcf/d and
3,758
MMcf/d for the three and
nine months ended September 30, 2018
, respectively, representing a
12%
and
4%
increase
, respectively, compared to the same periods in 2017.
|
•
|
Throughput for crude oil, NGL and produced water assets totaled
421
MBbls/d and
341
MBbls/d for the three and
nine months ended September 30, 2018
, respectively, representing a
101%
and
82%
increase
, respectively, compared to the same periods in 2017.
|
•
|
Operating income (loss) was
$200.3 million
for the three months ended
September 30, 2018
, representing a
12%
increase
compared to the same period in 2017. Operating income (loss) was
$463.2 million
for the
nine months ended September 30, 2018
, representing a
12%
decrease
compared to the same period in 2017.
|
•
|
Adjusted gross margin for natural gas assets (as defined under the caption
Key Performance Metrics
within this
Item 2
) averaged
$1.03
per Mcf and
$0.99
per Mcf for the three and
nine months ended September 30, 2018
, respectively, representing a
6%
and
8%
increase
, respectively, compared to the same periods in 2017.
|
•
|
Adjusted gross margin for crude oil, NGL and produced water assets (as defined under the caption
Key Performance Metrics
within this
Item 2
) averaged
$1.76
per Bbl and
$1.71
per Bbl for the three and
nine months ended September 30, 2018
, respectively, representing a
13%
and
17%
decrease
, respectively, compared to the same periods in 2017.
|
|
|
Three Months Ended
September 30, 2018 |
||||||||||
thousands
|
|
As Reported
|
|
Without Adoption of Topic 606
|
|
Effect of Change
Increase / (Decrease)
|
||||||
Revenues
|
|
|
|
|
|
|
||||||
Service revenues – fee based
|
|
$
|
409,106
|
|
|
$
|
396,161
|
|
|
$
|
12,945
|
|
Service revenues – product based
|
|
22,735
|
|
|
—
|
|
|
22,735
|
|
|||
Product sales
|
|
75,150
|
|
|
366,603
|
|
|
(291,453
|
)
|
|||
Expenses
|
|
|
|
|
|
|
||||||
Cost of product
|
|
105,966
|
|
|
353,641
|
|
|
(247,675
|
)
|
|||
Operation and maintenance
|
|
111,359
|
|
|
111,327
|
|
|
32
|
|
|||
Depreciation and amortization
|
|
82,553
|
|
|
81,824
|
|
|
729
|
|
|||
Income tax (benefit) expense
|
|
1,517
|
|
|
1,580
|
|
|
(63
|
)
|
|
|
Nine Months Ended
September 30, 2018 |
||||||||||
thousands
|
|
As Reported
|
|
Without Adoption of Topic 606
|
|
Effect of Change
Increase / (Decrease)
|
||||||
Revenues
|
|
|
|
|
|
|
||||||
Service revenues – fee based
|
|
$
|
1,146,099
|
|
|
$
|
1,096,708
|
|
|
$
|
49,391
|
|
Service revenues – product based
|
|
67,433
|
|
|
—
|
|
|
67,433
|
|
|||
Product sales
|
|
217,738
|
|
|
978,127
|
|
|
(760,389
|
)
|
|||
Expenses
|
|
|
|
|
|
|
|
|||||
Cost of product
|
|
303,518
|
|
|
940,936
|
|
|
(637,418
|
)
|
|||
Operation and maintenance
|
|
300,266
|
|
|
300,098
|
|
|
168
|
|
|||
Depreciation and amortization
|
|
238,187
|
|
|
236,102
|
|
|
2,085
|
|
|||
Impairments
|
|
152,708
|
|
|
152,663
|
|
|
45
|
|
|||
Income tax (benefit) expense
|
|
3,301
|
|
|
3,361
|
|
|
(60
|
)
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
thousands
|
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
Total revenues and other
(1)
|
|
$
|
507,762
|
|
|
$
|
574,695
|
|
|
$
|
1,432,483
|
|
|
$
|
1,616,338
|
|
Equity income, net – affiliates
|
|
43,110
|
|
|
21,519
|
|
|
102,752
|
|
|
62,708
|
|
||||
Total operating expenses
(1)
|
|
350,616
|
|
|
416,830
|
|
|
1,072,403
|
|
|
1,318,489
|
|
||||
Gain (loss) on divestiture and other, net
|
|
65
|
|
|
72
|
|
|
351
|
|
|
135,017
|
|
||||
Proceeds from business interruption insurance claims
(2)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
29,882
|
|
||||
Operating income (loss)
|
|
200,321
|
|
|
179,456
|
|
|
463,183
|
|
|
525,456
|
|
||||
Interest income – affiliates
|
|
4,225
|
|
|
4,225
|
|
|
12,675
|
|
|
12,675
|
|
||||
Interest expense
|
|
(47,991
|
)
|
|
(35,544
|
)
|
|
(131,663
|
)
|
|
(106,794
|
)
|
||||
Other income (expense), net
|
|
598
|
|
|
286
|
|
|
2,609
|
|
|
969
|
|
||||
Income (loss) before income taxes
|
|
157,153
|
|
|
148,423
|
|
|
346,804
|
|
|
432,306
|
|
||||
Income tax (benefit) expense
|
|
1,517
|
|
|
510
|
|
|
3,301
|
|
|
4,905
|
|
||||
Net income (loss)
|
|
155,636
|
|
|
147,913
|
|
|
343,503
|
|
|
427,401
|
|
||||
Net income attributable to noncontrolling interest
|
|
990
|
|
|
4,407
|
|
|
6,786
|
|
|
8,555
|
|
||||
Net income (loss) attributable to Western Gas Partners, LP
|
|
$
|
154,646
|
|
|
$
|
143,506
|
|
|
$
|
336,717
|
|
|
$
|
418,846
|
|
Key performance metrics
(3)
|
|
|
|
|
|
|
|
|
||||||||
Adjusted gross margin
|
|
$
|
431,561
|
|
|
$
|
344,416
|
|
|
$
|
1,178,400
|
|
|
$
|
1,009,520
|
|
Adjusted EBITDA
|
|
314,522
|
|
|
257,835
|
|
|
858,300
|
|
|
787,664
|
|
||||
Distributable cash flow
|
|
248,156
|
|
|
231,859
|
|
|
701,391
|
|
|
695,587
|
|
(1)
|
Revenues and other include amounts earned from services provided to our affiliates, as well as from the sale of residue and NGLs to our affiliates. Operating expenses include amounts charged by our affiliates for services, as well as reimbursement of amounts paid by affiliates to third parties on our behalf. See
Significant item affecting comparability
within this
Item 2
and
Note 6—Transactions with Affiliates
in the
Notes to Consolidated Financial Statements
under
Part I
,
Item 1
of this Form
10-Q
.
|
(2)
|
See
Note 1—Description of Business and Basis of Presentation
in the
Notes to Consolidated Financial Statements
under
Part I
,
Item 1
of this Form
10-Q
.
|
(3)
|
Adjusted gross margin, Adjusted EBITDA and Distributable cash flow are defined under the caption
Key Performance Metrics
within this
Item 2
.
For reconciliations of these non-GAAP financial measures to their most directly comparable financial measures calculated and presented in accordance with GAAP, see
Key Performance Metrics
–Reconciliation of non-GAAP measures
within this
Item 2
.
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||||
|
|
2018
|
|
2017
|
|
Inc/
(Dec) |
|
2018
|
|
2017
|
|
Inc/
(Dec)
|
||||||
Throughput for natural gas assets (MMcf/d)
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Gathering, treating and transportation
|
|
954
|
|
|
784
|
|
|
22
|
%
|
|
886
|
|
|
1,029
|
|
|
(14
|
)%
|
Processing
|
|
2,844
|
|
|
2,588
|
|
|
10
|
%
|
|
2,820
|
|
|
2,528
|
|
|
12
|
%
|
Equity investment
(1)
|
|
139
|
|
|
159
|
|
|
(13
|
)%
|
|
144
|
|
|
160
|
|
|
(10
|
)%
|
Total throughput for natural gas assets
|
|
3,937
|
|
|
3,531
|
|
|
11
|
%
|
|
3,850
|
|
|
3,717
|
|
|
4
|
%
|
Throughput attributable to noncontrolling interest for natural gas assets
|
|
87
|
|
|
104
|
|
|
(16
|
)%
|
|
92
|
|
|
107
|
|
|
(14
|
)%
|
Total throughput attributable to Western Gas Partners, LP for natural gas assets
|
|
3,850
|
|
|
3,427
|
|
|
12
|
%
|
|
3,758
|
|
|
3,610
|
|
|
4
|
%
|
Throughput for crude oil, NGL and produced water assets (MBbls/d)
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Gathering, treating, transportation and disposal
|
|
154
|
|
|
77
|
|
|
100
|
%
|
|
141
|
|
|
57
|
|
|
147
|
%
|
Equity investment
(2)
|
|
267
|
|
|
132
|
|
|
102
|
%
|
|
200
|
|
|
130
|
|
|
54
|
%
|
Total throughput for crude oil, NGL and produced water assets
|
|
421
|
|
|
209
|
|
|
101
|
%
|
|
341
|
|
|
187
|
|
|
82
|
%
|
(1)
|
Represents our 14.81% share of average Fort Union throughput and 22% share of average Rendezvous throughput.
|
(2)
|
Represents our 10% share of average White Cliffs throughput, 25% share of average Mont Belvieu JV throughput, 20% share of average TEG and TEP throughput, 33.33% share of average FRP throughput and 20% share of average Whitethorn throughput.
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||||||||
thousands except percentages
|
|
2018
|
|
2017
|
|
Inc/
(Dec)
|
|
2018
|
|
2017
|
|
Inc/
(Dec)
|
||||||||||
Service revenues – fee based
|
|
$
|
409,106
|
|
|
$
|
306,187
|
|
|
34
|
%
|
|
$
|
1,146,099
|
|
|
$
|
913,436
|
|
|
25
|
%
|
Service revenues – product based
|
|
22,735
|
|
|
—
|
|
|
NM
|
|
|
67,433
|
|
|
—
|
|
|
NM
|
|
||||
Total service revenues
|
|
$
|
431,841
|
|
|
$
|
306,187
|
|
|
41
|
%
|
|
$
|
1,213,532
|
|
|
$
|
913,436
|
|
|
33
|
%
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||||||||
thousands except percentages and
per-unit amounts
|
|
2018
|
|
2017
|
|
Inc/
(Dec)
|
|
2018
|
|
2017
|
|
Inc/
(Dec)
|
||||||||||
Natural gas sales
(1)
|
|
$
|
20,686
|
|
|
$
|
100,395
|
|
|
(79
|
)%
|
|
$
|
62,403
|
|
|
$
|
273,256
|
|
|
(77
|
)%
|
NGL sales
(1)
|
|
54,464
|
|
|
158,746
|
|
|
(66
|
)%
|
|
155,335
|
|
|
417,234
|
|
|
(63
|
)%
|
||||
Total Product sales
|
|
$
|
75,150
|
|
|
$
|
259,141
|
|
|
(71
|
)%
|
|
$
|
217,738
|
|
|
$
|
690,490
|
|
|
(68
|
)%
|
Gross average sales price per unit
(1)
:
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Natural gas (per Mcf)
|
|
$
|
2.01
|
|
|
$
|
2.89
|
|
|
(30
|
)%
|
|
$
|
2.15
|
|
|
$
|
2.96
|
|
|
(27
|
)%
|
Natural gas liquids (per Bbl)
|
|
34.43
|
|
|
22.99
|
|
|
50
|
%
|
|
32.09
|
|
|
21.63
|
|
|
48
|
%
|
(1)
|
Includes the effects of commodity price swap agreements for the MGR assets and DJ Basin complex, excluding the amounts considered above market with respect to these swap agreements that were recorded as capital contributions in the consolidated statement of equity and partners’ capital. See
Note 6—Transactions with Affiliates
in the
Notes to Consolidated Financial Statements
under
Part I
,
Item 1
of this Form
10-Q
.
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||||||||
thousands except percentages
|
|
2018
|
|
2017
|
|
Inc/
(Dec)
|
|
2018
|
|
2017
|
|
Inc/
(Dec)
|
||||||||||
Other revenues
|
|
$
|
771
|
|
|
$
|
9,367
|
|
|
(92
|
)%
|
|
$
|
1,213
|
|
|
$
|
12,412
|
|
|
(90
|
)%
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||||||||
thousands except percentages
|
|
2018
|
|
2017
|
|
Inc/
(Dec)
|
|
2018
|
|
2017
|
|
Inc/
(Dec)
|
||||||||||
Equity income, net – affiliates
|
|
$
|
43,110
|
|
|
$
|
21,519
|
|
|
100
|
%
|
|
$
|
102,752
|
|
|
$
|
62,708
|
|
|
64
|
%
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||||||||
thousands except percentages
|
|
2018
|
|
2017
|
|
Inc/
(Dec)
|
|
2018
|
|
2017
|
|
Inc/
(Dec)
|
||||||||||
NGL purchases
(1)
|
|
$
|
75,705
|
|
|
$
|
136,636
|
|
|
(45
|
)%
|
|
$
|
211,816
|
|
|
$
|
359,616
|
|
|
(41
|
)%
|
Residue purchases
(1)
|
|
25,389
|
|
|
90,264
|
|
|
(72
|
)%
|
|
72,461
|
|
|
256,387
|
|
|
(72
|
)%
|
||||
Other
|
|
4,872
|
|
|
12,323
|
|
|
(60
|
)%
|
|
19,241
|
|
|
15,856
|
|
|
21
|
%
|
||||
Cost of product
|
|
105,966
|
|
|
239,223
|
|
|
(56
|
)%
|
|
303,518
|
|
|
631,859
|
|
|
(52
|
)%
|
||||
Operation and maintenance
|
|
111,359
|
|
|
79,536
|
|
|
40
|
%
|
|
300,266
|
|
|
229,444
|
|
|
31
|
%
|
||||
Total Cost of product and Operation and maintenance expenses
|
|
$
|
217,325
|
|
|
$
|
318,759
|
|
|
(32
|
)%
|
|
$
|
603,784
|
|
|
$
|
861,303
|
|
|
(30
|
)%
|
(1)
|
For the three and
nine months ended September 30, 2017
, includes the effects of commodity price swap agreements for the MGR assets and DJ Basin complex, excluding the amounts considered above market with respect to these swap agreements that were recorded as capital contributions in the consolidated statement of equity and partners’ capital. See
Note 6—Transactions with Affiliates
in the
Notes to Consolidated Financial Statements
under
Part I
,
Item 1
of this Form
10-Q
.
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||||||||
thousands except percentages
|
|
2018
|
|
2017
|
|
Inc/
(Dec)
|
|
2018
|
|
2017
|
|
Inc/
(Dec)
|
||||||||||
General and administrative
|
|
$
|
14,467
|
|
|
$
|
12,158
|
|
|
19
|
%
|
|
$
|
42,634
|
|
|
$
|
35,402
|
|
|
20
|
%
|
Property and other taxes
|
|
10,954
|
|
|
11,215
|
|
|
(2
|
)%
|
|
35,090
|
|
|
35,433
|
|
|
(1
|
)%
|
||||
Depreciation and amortization
|
|
82,553
|
|
|
72,539
|
|
|
14
|
%
|
|
238,187
|
|
|
216,272
|
|
|
10
|
%
|
||||
Impairments
|
|
25,317
|
|
|
2,159
|
|
|
NM
|
|
|
152,708
|
|
|
170,079
|
|
|
(10
|
)%
|
||||
Total other operating expenses
|
|
$
|
133,291
|
|
|
$
|
98,071
|
|
|
36
|
%
|
|
$
|
468,619
|
|
|
$
|
457,186
|
|
|
3
|
%
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||||||||
thousands except percentages
|
|
2018
|
|
2017
|
|
Inc/
(Dec)
|
|
2018
|
|
2017
|
|
Inc/
(Dec)
|
||||||||||
Note receivable – Anadarko
|
|
$
|
4,225
|
|
|
$
|
4,225
|
|
|
—
|
%
|
|
$
|
12,675
|
|
|
$
|
12,675
|
|
|
—
|
%
|
Interest income – affiliates
|
|
$
|
4,225
|
|
|
$
|
4,225
|
|
|
—
|
%
|
|
$
|
12,675
|
|
|
$
|
12,675
|
|
|
—
|
%
|
Third parties
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Long-term debt
|
|
$
|
(52,935
|
)
|
|
$
|
(35,992
|
)
|
|
47
|
%
|
|
$
|
(142,612
|
)
|
|
$
|
(105,772
|
)
|
|
35
|
%
|
Amortization of debt issuance costs and commitment fees
|
|
(2,023
|
)
|
|
(1,667
|
)
|
|
21
|
%
|
|
(6,083
|
)
|
|
(4,942
|
)
|
|
23
|
%
|
||||
Capitalized interest
|
|
6,967
|
|
|
2,115
|
|
|
NM
|
|
|
17,032
|
|
|
3,991
|
|
|
NM
|
|
||||
Affiliates
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Deferred purchase price obligation – Anadarko
(1)
|
|
—
|
|
|
—
|
|
|
—
|
%
|
|
—
|
|
|
(71
|
)
|
|
(100
|
)%
|
||||
Interest expense
|
|
$
|
(47,991
|
)
|
|
$
|
(35,544
|
)
|
|
35
|
%
|
|
$
|
(131,663
|
)
|
|
$
|
(106,794
|
)
|
|
23
|
%
|
(1)
|
See
Note 3—Acquisitions and Divestitures
in the
Notes to Consolidated Financial Statements
under
Part I
,
Item 1
of this Form
10-Q
for a discussion of the Deferred purchase price obligation - Anadarko.
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||||||||
thousands except percentages
|
|
2018
|
|
2017
|
|
Inc/
(Dec) |
|
2018
|
|
2017
|
|
Inc/
(Dec) |
||||||||||
Income (loss) before income taxes
|
|
$
|
157,153
|
|
|
$
|
148,423
|
|
|
6
|
%
|
|
$
|
346,804
|
|
|
$
|
432,306
|
|
|
(20
|
)%
|
Income tax (benefit) expense
|
|
1,517
|
|
|
510
|
|
|
197
|
%
|
|
3,301
|
|
|
4,905
|
|
|
(33
|
)%
|
||||
Effective tax rate
|
|
1
|
%
|
|
—
|
%
|
|
|
|
|
1
|
%
|
|
1
|
%
|
|
|
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||||||||
thousands except percentages and per-unit amounts
|
|
2018
|
|
2017
|
|
Inc/
(Dec)
|
|
2018
|
|
2017
|
|
Inc/
(Dec)
|
||||||||||
Adjusted gross margin for natural gas assets
(1)
|
|
$
|
363,536
|
|
|
$
|
305,337
|
|
|
19
|
%
|
|
$
|
1,019,061
|
|
|
$
|
904,620
|
|
|
13
|
%
|
Adjusted gross margin for crude oil, NGL and produced water assets
(2)
|
|
68,025
|
|
|
39,079
|
|
|
74
|
%
|
|
159,339
|
|
|
104,900
|
|
|
52
|
%
|
||||
Adjusted gross margin
(3)
|
|
431,561
|
|
|
344,416
|
|
|
25
|
%
|
|
1,178,400
|
|
|
1,009,520
|
|
|
17
|
%
|
||||
Adjusted gross margin per Mcf for natural gas assets
(4)
|
|
1.03
|
|
|
0.97
|
|
|
6
|
%
|
|
0.99
|
|
|
0.92
|
|
|
8
|
%
|
||||
Adjusted gross margin per Bbl for crude oil, NGL and produced water assets
(5)
|
|
1.76
|
|
|
2.03
|
|
|
(13
|
)%
|
|
1.71
|
|
|
2.05
|
|
|
(17
|
)%
|
||||
Adjusted EBITDA
(3)
|
|
314,522
|
|
|
257,835
|
|
|
22
|
%
|
|
858,300
|
|
|
787,664
|
|
|
9
|
%
|
||||
Distributable cash flow
(3)
|
|
248,156
|
|
|
231,859
|
|
|
7
|
%
|
|
701,391
|
|
|
695,587
|
|
|
1
|
%
|
(1)
|
Adjusted gross margin for natural gas assets is calculated as total revenues and other for natural gas assets (less reimbursements for electricity-related expenses recorded as revenue), less cost of product for natural gas assets, plus distributions from our equity investments in Fort Union and Rendezvous, and excluding the noncontrolling interest owner’s proportionate share of revenue and cost of product. See the reconciliation of Adjusted gross margin for natural gas assets to its most comparable GAAP measure below.
|
(2)
|
Adjusted gross margin for crude oil, NGL and produced water assets is calculated as total revenues and other for crude oil, NGL and produced water assets (less reimbursements for electricity-related expenses recorded as revenue), less cost of product for crude oil, NGL and produced water assets, and plus distributions from our equity investments in White Cliffs, the Mont Belvieu JV, the TEFR Interests and Whitethorn. See the reconciliation of Adjusted gross margin for crude oil, NGL and produced water assets to its most comparable GAAP measure below.
|
(3)
|
For a reconciliation of Adjusted gross margin, Adjusted EBITDA and Distributable cash flow to the most directly comparable financial measure calculated and presented in accordance with GAAP, see the description below.
|
(4)
|
Average for period. Calculated as Adjusted gross margin for natural gas assets, divided by total throughput (MMcf/d) attributable to Western Gas Partners, LP for natural gas assets.
|
(5)
|
Average for period. Calculated as Adjusted gross margin for crude oil, NGL and produced water assets, divided by total throughput (MBbls/d) for crude oil, NGL and produced water assets.
|
•
|
our operating performance as compared to other publicly traded partnerships in the midstream industry, without regard to financing methods, capital structure or historical cost basis;
|
•
|
the ability of our assets to generate cash flow to make distributions; and
|
•
|
the viability of acquisitions and capital expenditure projects and the returns on investment of various investment opportunities.
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
thousands
|
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
Reconciliation of Operating income (loss) to Adjusted gross margin
|
|
|
|
|
|
|
|
|
||||||||
Operating income (loss)
|
|
$
|
200,321
|
|
|
$
|
179,456
|
|
|
$
|
463,183
|
|
|
$
|
525,456
|
|
Add:
|
|
|
|
|
|
|
|
|
||||||||
Distributions from equity investments
|
|
51,023
|
|
|
29,145
|
|
|
111,924
|
|
|
80,568
|
|
||||
Operation and maintenance
|
|
111,359
|
|
|
79,536
|
|
|
300,266
|
|
|
229,444
|
|
||||
General and administrative
|
|
14,467
|
|
|
12,158
|
|
|
42,634
|
|
|
35,402
|
|
||||
Property and other taxes
|
|
10,954
|
|
|
11,215
|
|
|
35,090
|
|
|
35,433
|
|
||||
Depreciation and amortization
|
|
82,553
|
|
|
72,539
|
|
|
238,187
|
|
|
216,272
|
|
||||
Impairments
|
|
25,317
|
|
|
2,159
|
|
|
152,708
|
|
|
170,079
|
|
||||
Less:
|
|
|
|
|
|
|
|
|
||||||||
Gain (loss) on divestiture and other, net
|
|
65
|
|
|
72
|
|
|
351
|
|
|
135,017
|
|
||||
Proceeds from business interruption insurance claims
|
|
—
|
|
|
—
|
|
|
—
|
|
|
29,882
|
|
||||
Equity income, net – affiliates
|
|
43,110
|
|
|
21,519
|
|
|
102,752
|
|
|
62,708
|
|
||||
Reimbursed electricity-related charges recorded as revenues
|
|
17,455
|
|
|
14,323
|
|
|
50,139
|
|
|
42,338
|
|
||||
Adjusted gross margin attributable to noncontrolling interest
|
|
3,803
|
|
|
5,878
|
|
|
12,350
|
|
|
13,189
|
|
||||
Adjusted gross margin
|
|
$
|
431,561
|
|
|
$
|
344,416
|
|
|
$
|
1,178,400
|
|
|
$
|
1,009,520
|
|
Adjusted gross margin for natural gas assets
|
|
$
|
363,536
|
|
|
$
|
305,337
|
|
|
$
|
1,019,061
|
|
|
$
|
904,620
|
|
Adjusted gross margin for crude oil, NGL and produced water assets
|
|
68,025
|
|
|
39,079
|
|
|
159,339
|
|
|
104,900
|
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
thousands
|
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
Reconciliation of Net income (loss) attributable to Western Gas Partners, LP to Adjusted EBITDA
|
|
|
|
|
|
|
|
|
||||||||
Net income (loss) attributable to Western Gas Partners, LP
|
|
$
|
154,646
|
|
|
$
|
143,506
|
|
|
$
|
336,717
|
|
|
$
|
418,846
|
|
Add:
|
|
|
|
|
|
|
|
|
||||||||
Distributions from equity investments
|
|
51,023
|
|
|
29,145
|
|
|
111,924
|
|
|
80,568
|
|
||||
Non-cash equity-based compensation expense
|
|
1,548
|
|
|
1,258
|
|
|
5,552
|
|
|
3,479
|
|
||||
Interest expense
|
|
47,991
|
|
|
35,544
|
|
|
131,663
|
|
|
106,794
|
|
||||
Income tax expense
|
|
1,517
|
|
|
510
|
|
|
3,301
|
|
|
4,905
|
|
||||
Depreciation and amortization
(1)
|
|
81,826
|
|
|
71,812
|
|
|
236,008
|
|
|
214,213
|
|
||||
Impairments
(1)
|
|
23,930
|
|
|
2,159
|
|
|
151,321
|
|
|
170,079
|
|
||||
Other expense
(1)
|
|
33
|
|
|
—
|
|
|
184
|
|
|
140
|
|
||||
Less:
|
|
|
|
|
|
|
|
|
||||||||
Gain (loss) on divestiture and other, net
|
|
65
|
|
|
72
|
|
|
351
|
|
|
135,017
|
|
||||
Equity income, net – affiliates
|
|
43,110
|
|
|
21,519
|
|
|
102,752
|
|
|
62,708
|
|
||||
Interest income – affiliates
|
|
4,225
|
|
|
4,225
|
|
|
12,675
|
|
|
12,675
|
|
||||
Other income
(1)
|
|
592
|
|
|
283
|
|
|
2,592
|
|
|
960
|
|
||||
Adjusted EBITDA
|
|
$
|
314,522
|
|
|
$
|
257,835
|
|
|
$
|
858,300
|
|
|
$
|
787,664
|
|
Reconciliation of Net cash provided by operating activities to Adjusted EBITDA
|
|
|
|
|
|
|
|
|
||||||||
Net cash provided by operating activities
|
|
$
|
236,811
|
|
|
$
|
211,947
|
|
|
$
|
751,722
|
|
|
$
|
645,099
|
|
Interest (income) expense, net
|
|
43,766
|
|
|
31,319
|
|
|
118,988
|
|
|
94,119
|
|
||||
Uncontributed cash-based compensation awards
|
|
(55
|
)
|
|
78
|
|
|
932
|
|
|
(94
|
)
|
||||
Accretion and amortization of long-term obligations, net
|
|
(1,257
|
)
|
|
(1,055
|
)
|
|
(3,883
|
)
|
|
(3,194
|
)
|
||||
Current income tax (benefit) expense
|
|
(14
|
)
|
|
395
|
|
|
247
|
|
|
1,023
|
|
||||
Other (income) expense, net
|
|
(598
|
)
|
|
(286
|
)
|
|
(2,609
|
)
|
|
(969
|
)
|
||||
Distributions from equity investments in excess of cumulative earnings – affiliates
|
|
5,592
|
|
|
7,034
|
|
|
18,097
|
|
|
16,255
|
|
||||
Changes in assets and liabilities:
|
|
|
|
|
|
|
|
|
||||||||
Accounts receivable, net
|
|
57,535
|
|
|
56,335
|
|
|
64,544
|
|
|
46,972
|
|
||||
Accounts and imbalance payables and accrued liabilities, net
|
|
(14,781
|
)
|
|
(45,982
|
)
|
|
(55,354
|
)
|
|
(4,007
|
)
|
||||
Other items, net
|
|
(9,379
|
)
|
|
3,181
|
|
|
(24,049
|
)
|
|
3,065
|
|
||||
Adjusted EBITDA attributable to noncontrolling interest
|
|
(3,098
|
)
|
|
(5,131
|
)
|
|
(10,335
|
)
|
|
(10,605
|
)
|
||||
Adjusted EBITDA
|
|
$
|
314,522
|
|
|
$
|
257,835
|
|
|
$
|
858,300
|
|
|
$
|
787,664
|
|
Cash flow information of Western Gas Partners, LP
|
|
|
|
|
|
|
|
|
||||||||
Net cash provided by operating activities
|
|
|
|
|
|
$
|
751,722
|
|
|
$
|
645,099
|
|
||||
Net cash used in investing activities
|
|
|
|
|
|
(1,160,684
|
)
|
|
(514,797
|
)
|
||||||
Net cash provided by (used in) financing activities
|
|
|
|
|
|
460,816
|
|
|
(335,792
|
)
|
(1)
|
Includes our 75% share of depreciation and amortization; impairments; other expense; and other income attributable to the Chipeta complex.
|
|
|
Three Months Ended
September 30, |
|
Nine Months Ended
September 30, |
||||||||||||
thousands except Coverage ratio
|
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
Reconciliation of Net income (loss) attributable to Western Gas Partners, LP to Distributable cash flow and calculation of the Coverage ratio
|
|
|
|
|
|
|
|
|
||||||||
Net income (loss) attributable to Western Gas Partners, LP
|
|
$
|
154,646
|
|
|
$
|
143,506
|
|
|
$
|
336,717
|
|
|
$
|
418,846
|
|
Add:
|
|
|
|
|
|
|
|
|
||||||||
Distributions from equity investments
|
|
51,023
|
|
|
29,145
|
|
|
111,924
|
|
|
80,568
|
|
||||
Non-cash equity-based compensation expense
|
|
1,548
|
|
|
1,258
|
|
|
5,552
|
|
|
3,479
|
|
||||
Non-cash settled interest expense, net
(1)
|
|
—
|
|
|
—
|
|
|
—
|
|
|
71
|
|
||||
Income tax (benefit) expense
|
|
1,517
|
|
|
510
|
|
|
3,301
|
|
|
4,905
|
|
||||
Depreciation and amortization
(2)
|
|
81,826
|
|
|
71,812
|
|
|
236,008
|
|
|
214,213
|
|
||||
Impairments
(2)
|
|
23,930
|
|
|
2,159
|
|
|
151,321
|
|
|
170,079
|
|
||||
Above-market component of swap agreements with Anadarko
(3)
|
|
12,601
|
|
|
18,049
|
|
|
40,722
|
|
|
46,719
|
|
||||
Other expense
(2)
|
|
33
|
|
|
—
|
|
|
184
|
|
|
140
|
|
||||
Less:
|
|
|
|
|
|
|
|
|
||||||||
Recognized Service revenues – fee based (less than) in excess of customer billings
(4)
|
|
4,397
|
|
|
—
|
|
|
536
|
|
|
—
|
|
||||
Gain (loss) on divestiture and other, net
|
|
65
|
|
|
72
|
|
|
351
|
|
|
135,017
|
|
||||
Equity income, net – affiliates
|
|
43,110
|
|
|
21,519
|
|
|
102,752
|
|
|
62,708
|
|
||||
Cash paid for maintenance capital expenditures
(2)
|
|
23,837
|
|
|
10,591
|
|
|
61,162
|
|
|
33,115
|
|
||||
Capitalized interest
|
|
6,967
|
|
|
2,115
|
|
|
17,032
|
|
|
3,991
|
|
||||
Cash paid for (reimbursement of) income taxes
|
|
—
|
|
|
—
|
|
|
(87
|
)
|
|
189
|
|
||||
Series A Preferred unit distributions
|
|
—
|
|
|
—
|
|
|
—
|
|
|
7,453
|
|
||||
Other income
(2)
|
|
592
|
|
|
283
|
|
|
2,592
|
|
|
960
|
|
||||
Distributable cash flow
|
|
$
|
248,156
|
|
|
$
|
231,859
|
|
|
$
|
701,391
|
|
|
$
|
695,587
|
|
Distributions declared
(5)
|
|
|
|
|
|
|
|
|
||||||||
Limited partners – common units
|
|
$
|
147,268
|
|
|
|
|
$
|
434,930
|
|
|
|
||||
General partner
|
|
82,971
|
|
|
|
|
242,133
|
|
|
|
||||||
Total
|
|
$
|
230,239
|
|
|
|
|
$
|
677,063
|
|
|
|
||||
Coverage ratio
|
|
1.08
|
|
x
|
|
|
1.04
|
|
x
|
|
(1)
|
Includes amounts related to the Deferred purchase price obligation - Anadarko. See
Note 3—Acquisitions and Divestitures
in the
Notes to Consolidated Financial Statements
under
Part I
,
Item 1
of this Form
10-Q
.
|
(2)
|
Includes our 75% share of depreciation and amortization; impairments; other expense; cash paid for maintenance capital expenditures; and other income attributable to the Chipeta complex.
|
(3)
|
See
Note 6—Transactions with Affiliates
in the
Notes to Consolidated Financial Statements
under
Part I
,
Item 1
of this Form
10-Q
.
|
(4)
|
See
Note 1—Description of Business and Basis of Presentation
in the
Notes to Consolidated Financial Statements
under
Part I
,
Item 1
of this Form
10-Q
.
|
(5)
|
Reflects cash distributions of
$0.965
and
$2.850
per unit declared for the three and
nine months ended September 30, 2018
, respectively.
|
•
|
maintenance capital expenditures, which include those expenditures required to maintain the existing operating capacity and service capability of our assets, such as to replace system components and equipment that have been subject to significant use over time, become obsolete or reached the end of their useful lives, to remain in compliance with regulatory or legal requirements or to complete additional well connections to maintain existing system throughput and related cash flows (for fiscal year 2018, the general partner’s Board of Directors has approved Estimated Maintenance Capital Expenditures (as defined in our partnership agreement) of $19.5 million per quarter); or
|
•
|
expansion capital expenditures, which include expenditures to construct new midstream infrastructure and those expenditures incurred to extend the useful lives of our assets, reduce costs, increase revenues or increase system throughput or capacity from current levels, including well connections that increase existing system throughput.
|
|
|
Nine Months Ended
September 30, |
||||||
thousands
|
|
2018
|
|
2017
|
||||
Acquisitions
|
|
$
|
162,112
|
|
|
$
|
159,208
|
|
|
|
|
|
|
||||
Expansion capital expenditures
|
|
$
|
887,843
|
|
|
$
|
384,416
|
|
Maintenance capital expenditures
|
|
61,179
|
|
|
33,391
|
|
||
Total capital expenditures
(1) (2)
|
|
$
|
949,022
|
|
|
$
|
417,807
|
|
|
|
|
|
|
||||
Capital incurred
(2)
|
|
$
|
923,407
|
|
|
$
|
504,286
|
|
(1)
|
Capital expenditures for the
nine months ended September 30, 2017
, are presented net of
$1.4 million
of contributions in aid of construction costs from affiliates.
|
(2)
|
For the
nine months ended September 30, 2018
and
2017
, included
$17.0 million
and
$4.0 million
, respectively, of capitalized interest.
|
|
|
Nine Months Ended
September 30, |
||||||
thousands
|
|
2018
|
|
2017
|
||||
Net cash provided by (used in):
|
|
|
|
|
||||
Operating activities
|
|
$
|
751,722
|
|
|
$
|
645,099
|
|
Investing activities
|
|
(1,160,684
|
)
|
|
(514,797
|
)
|
||
Financing activities
|
|
460,816
|
|
|
(335,792
|
)
|
||
Net increase (decrease) in cash and cash equivalents
|
|
$
|
51,854
|
|
|
$
|
(205,490
|
)
|
•
|
$949.0 million
of capital expenditures, primarily related to construction and expansion at the DBJV system and the DBM and DJ Basin complexes;
|
•
|
$161.9 million of cash paid for the acquisitions of the interests in Whitethorn and Cactus II;
|
•
|
$68.0 million
of capital contributions paid to Cactus II, the TEFR Interests, Whitethorn and White Cliffs for construction activities; and
|
•
|
$18.1 million
of distributions received from equity investments in excess of cumulative earnings.
|
•
|
$417.8 million
of capital expenditures, net of
$1.4 million
of contributions in aid of construction costs from affiliates, primarily related to plant construction and expansion at the DBM and DJ Basin complexes and the DBJV system;
|
•
|
$155.3 million of cash consideration paid as part of the Property Exchange;
|
•
|
$23.3 million of net proceeds from the sale of the Helper and Clawson systems in Utah;
|
•
|
$23.0 million
of proceeds from property insurance claims attributable to the incident at the DBM complex in 2015;
|
•
|
$16.3 million
of distributions received from equity investments in excess of cumulative earnings; and
|
•
|
$3.9 million
of cash paid for equipment purchases from Anadarko.
|
•
|
$1.08 billion of net proceeds from the offering of the 4.500% Senior Notes due 2028 and 5.300% Senior Notes due 2048 in March 2018, after underwriting and original issue discounts and offering costs, which were used to repay amounts outstanding under the RCF and for general partnership purposes, including to fund capital expenditures;
|
•
|
$738.1 million of net proceeds from the offering of the 4.750% Senior Notes due 2028 and 5.500% Senior Notes due 2048 in August 2018, after underwriting and original issue discounts and offering costs, which were used to repay the maturing 2.600% Senior Notes due August 2018, repay amounts outstanding under the RCF and for general partnership purposes, including to fund capital expenditures;
|
•
|
$690.0 million
of repayments of outstanding borrowings under the RCF;
|
•
|
$663.4 million
of distributions paid to our unitholders;
|
•
|
$350.0 million of principal repayment on the maturing 2.600% Senior Notes due August 2018;
|
•
|
$316.8 million of borrowings under the RCF, net of extension costs, which were used for general partnership purposes, including to fund capital expenditures;
|
•
|
$40.7 million
of capital contributions from Anadarko related to the above-market component of swap agreements; and
|
•
|
$9.4 million
of distributions paid to the noncontrolling interest owner of Chipeta.
|
•
|
$589.3 million
of distributions paid to our unitholders;
|
•
|
$250.0 million
of borrowings under the RCF, which were used for general partnership purposes;
|
•
|
$46.7 million
of capital contributions from Anadarko related to the above-market component of swap agreements;
|
•
|
$37.3 million
of cash paid to Anadarko for the settlement of the Deferred purchase price obligation - Anadarko; and
|
•
|
$9.0 million
of distributions paid to the noncontrolling interest owner of Chipeta.
|
thousands except unit amounts
Quarters Ended
|
|
PIK Class C Units
|
|
Implied Fair Value
|
|
Date of
Distribution |
|||
2017
|
|
|
|
|
|
|
|||
December 31
|
|
261,394
|
|
|
$
|
13,674
|
|
|
February 2018
|
2018
|
|
|
|
|
|
|
|||
March 31
|
|
272,988
|
|
|
$
|
12,901
|
|
|
May 2018
|
June 30
|
|
267,164
|
|
|
12,998
|
|
|
August 2018
|
Exhibit
Number
|
|
Description
|
2.1#
|
|
|
2.2#
|
|
|
2.3#
|
|
|
2.4#
|
|
|
2.5#
|
|
|
2.6#
|
|
|
2.7#
|
|
|
2.8#
|
|
|
2.9#
|
|
|
2.10#
|
|
Exhibit
Number
|
|
Description
|
2.11#
|
|
|
2.12#
|
|
|
2.13#
|
|
|
2.14#
|
|
|
3.1
|
|
|
3.2
|
|
|
3.3
|
|
|
3.4
|
|
|
3.5
|
|
|
3.6
|
|
|
3.7
|
|
|
4.1
|
|
|
4.2
|
|
|
4.3
|
|
|
4.4
|
|
|
4.5
|
|
Exhibit
Number
|
|
Description
|
4.6
|
|
|
4.7
|
|
|
4.8
|
|
|
4.9
|
|
|
4.10
|
|
|
4.11
|
|
|
4.12
|
|
|
4.13
|
|
|
4.14
|
|
|
4.15
|
|
|
4.16
|
|
|
4.17
|
|
|
4.18
|
|
|
4.19
|
|
|
4.20
|
|
|
4.21
|
|
Exhibit
Number
|
|
Description
|
4.22
|
|
|
10.1*†
|
|
|
31.1*
|
|
|
31.2*
|
|
|
32.1**
|
|
|
101.INS*
|
|
XBRL Instance Document
|
101.SCH*
|
|
XBRL Schema Document
|
101.CAL*
|
|
XBRL Calculation Linkbase Document
|
101.DEF*
|
|
XBRL Definition Linkbase Document
|
101.LAB*
|
|
XBRL Label Linkbase Document
|
101.PRE*
|
|
XBRL Presentation Linkbase Document
|
#
|
Pursuant to Item 601(b)(2) of Regulation S-K, the registrant agrees to furnish supplementally a copy of any omitted schedule to the Securities and Exchange Commission upon request.
|
†
|
Portions of this exhibit, which was previously filed with the Securities and Exchange Commission, were omitted pursuant to a request for confidential treatment. The omitted portions were filed separately with the Securities and Exchange Commission.
|
|
WESTERN GAS PARTNERS, LP
|
|
|
October 31, 2018
|
|
|
|
|
/s/ Benjamin M. Fink
|
|
Benjamin M. Fink
President and Chief Executive Officer
Western Gas Holdings, LLC
(as general partner of Western Gas Partners, LP)
|
|
|
October 31, 2018
|
|
|
|
|
/s/ Jaime R. Casas
|
|
Jaime R. Casas
Senior Vice President, Chief Financial Officer and Treasurer
Western Gas Holdings, LLC
(as general partner of Western Gas Partners, LP)
|
|
(a)
|
Nitrogen
|
Not more than ***% by volume
|
|
(b)
|
Oxygen
|
Not more than *** PPM
|
|
(c)
|
Carbon Dioxide
|
Not more than ***% by volume
|
|
(d)
|
Hydrogen Sulfide
|
Not more than *** PPM
|
|
(e)
|
Mercaptan Sulfur
|
Not more than *** grain per *** cubic feet
|
|
(f)
|
Total Sulfur
|
Not more than *** *** per *** cubic feet
|
|
(g)
|
Free Water
|
***
|
|
(h)
|
Heating Value Lean Gas
|
Not more than *** Btu per cubic foot
|
|
(i)
|
Heating Value Rich Gas
|
Not less than *** Btu per cubic foot
|
|
(j)
|
Temperature
|
Not less than ***° and not more than ***° Fahrenheit
|
Calendar Year
|
HP Rich Gathering Fee
|
LP Rich Gathering Fee
|
2018-2027
|
$***/Mcf
|
Cost of service as determined by DBM each calendar year pursuant to
Section 6.3
below; subject to adjustment by the Rate Reduction Incentive set out in
Section 6.4
below.
|
2028-2032
|
$***/Mcf
|
Fixed rate equal to $***/Mcf.
|
CO
2
Content
(mole %)
|
Total CO
2
Treating Fee
($/Mcf)
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
H
2
S (PPM)
|
Total H
2
S Disposal Fee ($/Mcf)
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
***
|
(a)
|
For good and valuable consideration, the receipt and sufficiency of which will be acknowledged, AEP will, to the maximum extent it has the right to do so, grant, bargain, sell, convey, transfer, assign and deliver unto DBM, from a time before the assignment until the end of the Term, unless earlier reverted in accordance with the terms of this Agreement, the sole and exclusive right to transport Gas from AEP’s assigned Dedicated Lands, specifically the right to gather, dehydrate, compress, meter and measure Gas that may be produced and saved therefrom (the
“
Transportation Interests
”
).
|
(b)
|
At the end of the Term or upon the earlier termination of this Agreement as to any Dedicated Lands in accordance with any express provision of this Agreement, all of DBM’s Transportation Interests applicable to such Dedicated Lands will revert automatically to AEP (or its assignee, as appropriate) or the other applicable owners thereof, and DBM shall execute and deliver to AEP (or its assignee, as appropriate) a recordable release and quitclaim in and to any rights, including Transportation Interests, in such Dedicated Lands.
|
(c)
|
The Transportation Interests conveyed to DBM will be subject to (i) the terms and conditions of this Agreement and (ii) with respect to third party non-operated interests, the rights (if any) of the owners of such interests to take in kind their share of Gas produced from the Dedicated Lands.
|
(d)
|
DBM and AEP agree, and the conveyance document shall affirmatively state, that (i) the rights and obligations respecting the Dedication and the Transportation Interest constitute a covenant running with the Interest of AEP in the Dedicated Lands, and as such shall be binding upon and enforceable by each Party and its permitted successors and assigns against the other Party and its successors and assigns respecting any part of a subject interest so assigned or conveyed, (ii) DBM and AEP intend that the conveyance of the Transportation Interests be a conveyance of a portion of AEP’s real property interests included in the Dedicated Lands (including the interests of others whose interests are represented or controlled by AEP insofar only as AEP has the power and authority to grant a Transportation Interest in the interests of such third parties), and (iii) DBM has a determinable real property interest carved out of the Dedicated Lands.
|
(e)
|
In connection with the release of Transportation Interests, if any, DBM and AEP shall execute and deliver any additional documents and instruments and perform any additional acts that may become reasonably necessary or appropriate to effectuate the reversion of such Transportation Interests.
|
(f)
|
AEP shall (and shall cause its Affiliates to) cause any conveyance of part or all of an Interest in the Dedicated Lands to be made expressly subject to this Transportation Interest and to cause all transferees to execute a written instrument in a form reasonably satisfactory to DBM acknowledging the conveyance of the Transportation Interests. DBM shall likewise cause any assignment or conveyance of the Transportation Interests to be made expressly subject to this Agreement. DBM and AEP shall promptly execute, acknowledge, deliver and record in the land records of the applicable jurisdiction(s) a short form Transportation Interest Conveyance in the form of
Exhibit “H”
(the “
Conveyance
”).
|
DELAWARE BASIN MIDSTREAM, LLC
|
|
ANADARKO E&P ONSHORE LLC
|
||
|
|
|
|
|
|
|
|
|
|
By:
|
/s/ Gennifer F. Kelly
|
|
By:
|
/s/ Chad R. McAllaster
|
Name:
|
Gennifer F. Kelly
|
|
Name:
|
Chad R. McAllaster
|
Title:
|
SVP and COO
|
|
Title:
|
VP, Delaware Basin Development
|
Date:
|
October 8, 2018
|
|
Date:
|
October 2, 2018
|
STATE OF TEXAS
|
§
|
|
COUNTY OF LOVING
|
§
|
|
H.
|
Covenant.
The Agreement constitutes a covenant running with the land and shall inure to the benefit of and be binding upon the parties hereto and their respective successors and assigns.
|
I.
|
Notice
. By this Memorandum, all parties dealing with the Dedicated Lands are hereby put on notice as to the rights and obligations of AEP and DBM under the Agreement.
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STATE OF TEXAS
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§
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§
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COUNTY OF
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§
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Notary Public
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My commission expires:
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STATE OF TEXAS
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§
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§
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COUNTY OF
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§
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Notary Public
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My commission expires:
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STATE OF TEXAS
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§
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COUNTY OF REEVES
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§
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Q.
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Covenant.
The Agreement constitutes a covenant running with the land and shall inure to the benefit of and be binding upon the parties hereto and their respective successors and assigns.
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R.
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Notice
. By this Memorandum, all parties dealing with the Dedicated Lands are hereby put on notice as to the rights and obligations of AEP and DBM under the Agreement.
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STATE OF TEXAS
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§
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§
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COUNTY OF
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§
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Notary Public
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My commission expires:
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STATE OF TEXAS
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§
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§
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COUNTY OF
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§
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Notary Public
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My commission expires:
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STATE OF TEXAS
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§
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COUNTY OF WARD
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§
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Z.
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Covenant.
The Agreement constitutes a covenant running with the land and shall inure to the benefit of and be binding upon the parties hereto and their respective successors and assigns.
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AA.
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Notice
. By this Memorandum, all parties dealing with the Dedicated Lands are hereby put on notice as to the rights and obligations of AEP and DBM under the Agreement.
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STATE OF TEXAS
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§
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§
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COUNTY OF
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§
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Notary Public
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My commission expires:
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STATE OF TEXAS
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§
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§
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COUNTY OF
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§
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Notary Public
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My commission expires:
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STATE OF TEXAS
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§
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COUNTY OF WINKLER
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§
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II.
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Covenant.
The Agreement constitutes a covenant running with the land and shall inure to the benefit of and be binding upon the parties hereto and their respective successors and assigns.
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JJ.
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Notice
. By this Memorandum, all parties dealing with the Dedicated Lands are hereby put on notice as to the rights and obligations of AEP and DBM under the Agreement.
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STATE OF TEXAS
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§
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§
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COUNTY OF
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§
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Notary Public
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My commission expires:
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STATE OF TEXAS
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§
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§
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COUNTY OF
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§
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Notary Public
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My commission expires:
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DBM
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AEP
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Delaware Basin Midstream, LLC
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Anadarko E&P Onshore LLC
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||
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By:
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By:
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Name:
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Name:
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Title:
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Title:
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STATE OF
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§
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§
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COUNTY OF
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§
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Notary Public
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My commission expires:
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STATE OF
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§
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§
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COUNTY OF
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§
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Notary Public
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My commission expires:
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1.
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I have reviewed this
quarterly
report on Form
10-Q
of Western Gas Partners, LP (the “registrant”);
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2.
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Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
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3.
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Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
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4.
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The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
(a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
(b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
(c)
|
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
(d)
|
Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
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5.
|
The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
|
(a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
|
(b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
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/s/ Benjamin M. Fink
|
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Benjamin M. Fink
President and Chief Executive Officer
Western Gas Holdings, LLC
(as general partner of Western Gas Partners, LP)
|
1.
|
I have reviewed this
quarterly
report on Form
10-Q
of Western Gas Partners, LP (the “registrant”);
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
4.
|
The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
(a)
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including
its consolidated subsidiaries, is made known to us by others within those entities, particularly during the
period in which this report is being prepared;
|
(b)
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
(c)
|
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
(d)
|
Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
|
5.
|
The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
|
(a)
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
|
(b)
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
|
|
/s/ Jaime R. Casas
|
|
Jaime R. Casas
Senior Vice President, Chief Financial Officer and Treasurer
Western Gas Holdings, LLC
(as general partner of Western Gas Partners, LP)
|
(1)
|
the
Quarterly
Report on Form
10-Q
of the Partnership for the period ending
September 30, 2018
, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
|
(2)
|
the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.
|
October 31, 2018
|
|
|
|
|
|
|
|
/s/ Benjamin M. Fink
|
|
|
Benjamin M. Fink
President and Chief Executive Officer
Western Gas Holdings, LLC
(as general partner of Western Gas Partners, LP)
|
|
|
|
October 31, 2018
|
|
|
|
|
|
|
|
/s/ Jaime R. Casas
|
|
|
Jaime R. Casas
Senior Vice President, Chief Financial Officer and Treasurer
Western Gas Holdings, LLC
(as general partner of Western Gas Partners, LP)
|