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Supplemental Oil and Gas Reserve Information
 12 Months Ended
Dec. 31, 2016
Extractive Industries [Abstract]  
Supplemental Oil and Gas Reserve Information
Supplemental Oil and Gas Reserve Information
 
The estimates of proved oil and gas reserves utilized in the preparation of the consolidated financial statements were prepared by independent petroleum engineers.  Such estimates are in accordance with guidelines established by the Securities and Exchange Commission and the FASB.  All of our reserves are located in the United States.  For information about our results of operations from oil and gas activities, see the accompanying consolidated statements of operations and comprehensive income (loss).
 
We emphasize that reserve estimates are inherently imprecise.  Accordingly, the estimates are expected to change as more current information becomes available.  In addition, a portion of our proved reserves are classified as proved developed nonproducing and proved undeveloped, which increases the imprecision inherent in estimating reserves which may ultimately be produced.
 
We did not have any capital costs relating to exploratory wells pending the determination of proved reserves for the years ended 2016, 2015 and 2014.
 
The following table sets forth estimated proved reserves together with the changes therein (oil and NGL in MBbls, gas in MMcf, gas converted to MBOE by dividing MMcf by six) for the years ended 2016, 2015 and 2014.
 
 
Oil
 
Natural Gas Liquids
 
 Natural Gas
 
MBOE
Proved reserves:
 

 
 

 
 

 
 

December 31, 2013
48,665

 
8,487

 
77,179

 
70,015

Extensions and discoveries
19,032

 
2,298

 
12,034

 
23,336

Revisions
(7,786
)
 
(1,160
)
 
(6,934
)
 
(10,101
)
Sales of minerals-in-place
(1,850
)
 
(73
)
 
(803
)
 
(2,057
)
Production
(4,194
)
 
(585
)
 
(5,901
)
 
(5,763
)
December 31, 2014
53,867

 
8,967

 
75,575

 
75,430

Extensions and discoveries
2,669

 
407

 
2,796

 
3,542

Revisions
(18,912
)
 
(3,344
)
 
(23,414
)
 
(26,158
)
Sales of minerals-in-place
(291
)
 
(12
)
 
(1,016
)
 
(472
)
Production
(4,257
)
 
(550
)
 
(5,794
)
 
(5,773
)
December 31, 2015
33,076

 
5,468

 
48,147

 
46,569

Extensions and discoveries
2,864

 
604

 
3,651

 
4,077

Revisions
553

 
(48
)
 
(4,036
)
 
(168
)
Sales of minerals-in-place
(8,523
)
 
(656
)
 
(9,292
)
 
(10,728
)
Production
(3,623
)
 
(557
)
 
(4,893
)
 
(4,996
)
December 31, 2016
24,347

 
4,811

 
33,577

 
34,754

Proved developed reserves:
 

 
 

 
 

 
 

December 31, 2014
29,059

 
4,668

 
51,072

 
42,239

December 31, 2015
25,349

 
4,266

 
39,987

 
36,280

December 31, 2016
14,540

 
3,335

 
24,620

 
21,978




CLAYTON WILLIAMS ENERGY, INC.
SUPPLEMENTAL INFORMATION (Continued)
(UNAUDITED)

The 168 MBOE of net downward revisions in proved reserves for 2016 resulted from a combination of (1) net upward revisions of 11,670 MBOE related primarily to performance in our Delaware Basin program, and (2) downward revisions of 11,838 MBOE related to the effects of lower commodity prices on the estimated quantities of proved reserves.  

The standardized measure of discounted future net cash flows relating to estimated proved reserves as of 2016, 2015 and 2014 was as follows:
 
 
2016
 
2015
 
2014
 
(In thousands)
Future cash inflows
$
1,035,786

 
$
1,721,207

 
$
5,479,211

Future costs:
 
 
 
 
 
Production
(424,092
)
 
(711,887
)
 
(1,719,989
)
Abandonment
(65,852
)
 
(120,737
)
 
(149,112
)
Development
(148,108
)
 
(147,189
)
 
(695,180
)
Income taxes
(12,204
)
 
(38,306
)
 
(833,601
)
Future net cash flows
385,530

 
703,088

 
2,081,329

10% discount factor
(226,567
)
 
(312,445
)
 
(1,148,416
)
Standardized measure of discounted net cash flows
$
158,963

 
$
390,643

 
$
932,913


 
Changes in the standardized measure of discounted future net cash flows relating to estimated proved reserves for the years ended 2016, 2015 and 2014 were as follows:
 
 
2016
 
2015
 
2014
 
(In thousands)
Standardized measure, beginning of period
$
390,643

 
$
932,913

 
$
926,923

Net changes in sales prices, net of production costs
(71,603
)
 
(965,126
)
 
(94,104
)
Revisions of quantity estimates
329

 
(245,035
)
 
(234,612
)
Accretion of discount
44,278

 
137,998

 
138,095

Changes in future development costs, including development costs incurred that reduced future development costs
10,145

 
308,261

 
146,392

Changes in timing and other
(29,458
)
 
(69,160
)
 
(70,774
)
Net change in income taxes
9,068

 
395,888

 
2,893

Future abandonment cost, net of salvage
(2,357
)
 
(2,968
)
 
4,066

Extensions and discoveries
39,678

 
48,367

 
431,895

Sales, net of production costs
(84,384
)
 
(126,455
)
 
(309,758
)
Sales of minerals-in-place
(147,376
)
 
(24,040
)
 
(8,103
)
Standardized measure, end of period
$
158,963

 
$
390,643

 
$
932,913


 




CLAYTON WILLIAMS ENERGY, INC.
SUPPLEMENTAL INFORMATION (Continued)
(UNAUDITED)

The estimated present value of future cash flows relating to estimated proved reserves is extremely sensitive to prices used at any measurement period.  Average prices for 2016, 2015 and 2014 were based on the 12-month unweighted arithmetic average of the first-day-of-the-month prices for the period from January through December during each respective calendar year. These benchmark average prices were further adjusted for quality, energy content, transportation fees and other price differentials specific to our properties. The average prices used for each commodity for the years ended 2016, 2015 and 2014 were as follows:
 
 
Average Price
 
Oil
 
Natural Gas Liquids
 
Natural Gas
 
($/Bbl)
 
($/Bbl)
 
($/Mcf)
As of December 31:
 

 
 
 
 

2016
$
36.60

 
$
13.60

 
$
2.36

2015
$
45.75

 
$
15.84

 
$
2.52

2014
$
90.48

 
$
31.54

 
$
4.27