· new mexico public regulation commission att: mr. ronald x. montoya 1120 paseo de peralta santa...

entral Va ey ooperative, Inc. P. 0. Box 230 1505 North Thirteenth Street

CHARLES T. PINSON JR. FAX Executive Vice President (575) 746-4219

& General Manager

New Mexico Public Regulation Commission Att: Mr. Ronald X. Montoya 1120 Paseo de Peralta Santa Fe NM 87501

April 28, 2010

RE: Annual Report 2009

Dear Mr. Montoya:

Artesia, New Mexico 88211

TELEPHONE (575)746-3571 (575)752-3366

' '

,-::, CT)

On behalf of Central Valley Electric Cooperative, Inc. (CVEC) we are submitting our completed Annual Report and load forecast.

Should you require additional information, please advise.

Sincerely,

CENTRAL VALLEY ELECTRIC

~~: Assistant Manager

Enclosures

MA/jm

~:· ~: ~ -: ;::; ::;::

( , (,-) ni '.,, ".-'> c:::: X

- -- .-- --C) :... 0

.. : ~::::;,

SUMMER LOAD FORECAST DEMAND (JULY)

SPP Bus#

527514 527589 527626 527650 527657 527664 527692 527754 527763 527821 527828 527943 528003 5280/6 528079 528109 528116

INTERRUPTIBLE LOAD

SPP Bus#

527514 527589 527626 527650 527657 527664 527692 527754 527763 527821 527828 527943 528003 528076 528079 528109 528116

Table 1 Summer Demand

Delivery Point Name Delivery Point Power Voltage

Ownership Factor (kV)

CV-PINE 2 CVEC 95% 69 CV-ORCHARD 2 CVEC 95% 69 CV-DEXTER 2 CVEC 95% 69

CV-HAGERMAN2 CVEC 95% 69 CV-LAKARTHR2 CVEC 95% 69

CV-CTTNWOOD2 CVEC 95% 69 CV-YO 2 CVEC 95% 69

CV-ARTESIA 2 CVEC 95% 69 CV-W ARTSIA2 CVEC 95% 69 CV-DAYTON 3 CVEC 95% 115 CV-12MH 3 CVEC 95% 115 CV-LUSK 2 CVEC 95% 69

CV-DAGGR&IH2 CVEC 95% 69 CV-VVAL TCYN 3 CVFC 95% 115 CV-CONEBUTE3 CVEC 95% 115 CV-LAKEWOOD3 CVEC 95% 115

CV-IRISHHIL3 CVEC 95% 115 Sum of Projected Substation

Loads

Need breakdown by substation of amount of load that is interruptible

Substation Bus Name Delivery Point Voltage

Ownership (kV)

CV-PINE 2 CVEC 69 CV-ORCHARD 2 CVEC "" Uv

CV-DEXTER 2 CVEC 69 CV-HAGERMAN2 CVEC 69 CV-LAKARTHR2 CVEC 69

CV-CTTNWOOD2 CVEC 69 CV-YO 2 CVEC 69

CV-ARTESIA 2 CVEC 69 CV-W ARTSIA2 CVEC 69 CV-DAYTON 3 CVEC 115 CV-12MH 3 CVEC 115 CV-LUSK 2 CVEC 69

CV-DAGGR&IH2 CVEC 69 CV-WAL TCYN 3 CVEC 115 CV-CONEBUTE3 CVEC 115 CV-LAKEWOOD3 CVEC 115

CV-IRISHHIL3 CVEC 115

TOTAL INTERRUPTIBLE LOAD

TOTAL LOAD· Summer

2010 2011 2012 2016 2021 (MW) (MW) (MW) (MW) (MW)

8.3 8.1 7.9 7.1 6.3 5.8 5.9 6.1 6.6 7.2 7.6 7.6 7.6 7.8 8.0 4.1 4.2 4.2 4.4 4.6 2.4 2.4 2.4 2.4 2.5 3.9 3.9 3.9 4.1 4.3 2.2 2.3 2.4 2.6 3.0 8.8 9.0 9.3 10.3 11.7 6.2 6.3 6.5 7.2 8.2 5.4 5.3 5.1 4.6 4.1

27.7 27.0 26.3 23.8 20.9 6.5 6.4 6.2 5.6 4.9

14.6 13.7 12.8 9.8 7.0 12.5 11.9 11.4 9.5 7.5 6.3 5.9 5.5 4.Z 3.0 3.2 3.2 3.2 3.3 3.3 4.1 3.8 3.5 2.7 1.9

129.5 126.8 124.3 115.9 108.5

129.5 126.8 124.3 115.9 108.5 ...

'- -2010 2011 2012 2016 2021~ {MW) (MW) (MW) (MW) {MWr

. -r r,

~ ·:--: ::3 ..-A \., _ _,\ C)

C)

-

1.4 1.4 1.4 1.4 1.4

1.4 1.4 1.4 1.4 1.4

128.1 125.4 122.9 114.5 107.1

WINTER LOAD FORECAST DEMAND (DECEMBER)

SPP Bus#

527514 527589 527626 527650 527657 527664 527692 527754 527763 527821 527828 527943 528003 528076 528079 528109 528116

INTERRUPTIBLE LOAD

SPP Bus#

527514 527589 !---------527626 527650 527657 527664 527692 527754 527763 527821 527828 527943 528003 528076 528079 528109 528116

I

Table 2 Winter Demand







CV-DAGGR&IH2 CVEC 95% 69 ,-.\ I \!\I I\ I Tl"""<'\/llb. I -, vv-vVML IV l I\!..) CVEC 95% i 15 CV-CONEBUTE3 CVEC 95% 115 CV-LAKEWOOD3 CVEC 95% 115

CV-IRISHHiL3 CVEC 95% 115 Sum of Projected Substation

Loads



Ownership (kV)

CV-PINE 2 CVEC 69 CV-ORCHARD 2 CVEC 69 CV-DEXTER 2 CVEC 69

CV-HAGERMAN2 CVEC 69 CV-LAKARTHR2 CVEC 69


CV-ARTESIA 2 CVEC 69 CV-W ARTSIA2 CVEC 69 CV-DAYTON 3 CVEC 115 CV-12MH 3 CVEC 115 CV-LUSK 2 CVEC 69

CV-DAGGR&IH2 CVEC 69 CV-WALTCYN 3 CVEC 115 CV-CONEBUTE3 CVEC 115 CV-LAKEWOOD3 CVEC 115



TOT AL LOAD • Winter

- ,,-

2010 2011 2012 2016 (MW) (MW) (MW) (MW)

6.3 6.1 5.9 5.4 4.2 4.3 4.4 4.8 4.9 4.9 4.9 5.0 2.7 2.7 2.8 2.9 1.2 1.2 1.2 1.2 2.7 2.7 2.7 2.9 1.8 1.8 1.8 2.0 6.6 6.8 7.0 7.7 4.6 4.8 4.9 5.4 4.0 3.9 3.8 3.4

27.7 27.0 26.3 23.8 6.5 6.4 6.2 5.6

14.6 13.7 12.8 9.8 12.5 11.9 11.4 9.5 6.3 5.9 5.5 4.2 2.1 2.1 2.1 2.2 4.1 3.8 3.5 2.7

112.8 110.0 107.4 98.5

112.8 110.0 107.4 98.5

2010 2011 2012 2016 (MW) (MW) (MW) (MW)

1.4 1.4 1.4 1.4

1.4 1.4 1.4 1.4

111.4 108.6 106.0 97.1

Fall LOAD FORECAST DEMAND (OCTOBER)

SPP Bus#

527514 527589 527626 527650 527657 527664 527692 527754 527763 527821 527828 527943 528003 528076 528079 528109 528116

INTERRUPTIBLE LOAD

SPP Bus#

527514 .527!'i8!=! 527626 527650 527657 527664 527692 527754 527763 527821 527828 527943 528003 528076 528079 528109 528116

Table 3 Fall Demand







CV-DAGGR&IH2 CVEC 95% 69 CV-\1\/A.LTCYN 3 CVEC 95% 115 CV-CONEBUTE3 CVEC 95% 115 CV-LAKE\I\/OOD3 CVEC 95% 115

CV-IRISHHIL3 CVEC 95% 115 Sum of Projected Substation

Loads



Ownership (kV)

CV-PINE 2 CVEC 69 CV-OR(.;HARD 2 /""'\/Cr,

vv II.-'-" 69 CV-DEXTER 2 L:VEC

,,,... v;:,

CV-HAGERMAN2 CVEC 69 CV-LAKARTHR2 CVEC 69


CV-ARTESIA 2 CVEC 69 CV-W_ARTSIA2 CVEC 69 CV-DAYTON 3 CVEC 115 CV-12MH 3 CVEC 115 CV-LUSK 2 CVEC 69

CV-DAGGR&IH2 CVEC 69 CV-WAL TCYN 3 CVEC 115 CV-CONEBUTE3 CVEC 115 CV-LAKEWOOD3 CVEC 115



TOTAL LOAD· Fall

2010 2011 (MW) (MW)

7.1 6.9 4.0 4.1 5.1 5.1 2.8 2.9 1.8 1.9 2.6 2.6 1.7 1.8 7.3 7.5 5.1 5.2 4.9 4.8

27.7 27.0 6.5 6.4

14.6 13.7 12.5 11.9 6.3 5.9 2.7 2.7 4.1 3.8

116.8 114.0

116.8 114.0

2010 2011 (MW) (MW)

1.4 1.4

1.4 1.4

115.4 112.6

Table 4 Spring Demand

Spring LOAD FORECAST DEMAND (April)

Delivery Point Power Voltage 2010 2011 2011 Apr

SPP Bus# Delivery Point Name Ownership Factor (kV) (MW) (MW)

Min (MW\

527514 CV-PINE 2 CVEC 95% 69 7.3 7.1 7.1 527589 CV-ORCHARD 2 CVEC 95% 69 4.4 4.5 4.5 527626 CV-DEXTER 2 CVEC 95% 69 7.1 7.1 7.1 527650 CV-HAGERMAN2 CVEC 95% 69 3.4 3.5 3.5 527657 CV-LAKARTHR2 CVEC 95% 69 2.2 2.2 2.2 527664 CV-CTTNWOOD2 CVEC 95% 69 3.4 3.4 3.4 527692 CV-YO 2 CVEC 95% 69 2.2 2.3 2.3 527754 CV-ARTESIA 2 CVEC 95% 69 7.3 7.5 7,5 527763 CV-W ARTSIA2 CVEC 95% 69 5.1 5.3 5.3 527821 CV-DAYTON 3 CVEC 95% 115 3.6 3.5 3.5 527828 CV-12MH 3 CVEC 95% 115 27.7 27.0 27.0 527943 CV-LUSK 2 CVEC 95% 69 6.5 6.4 6.4 528003 CV-DAGGR&IH2 CVEC 95% 69 14.6 13.7 13.7 528076 CV-\/JAL TCYN 3 CVEC 95% 115 12.5 11.9 11.9 528079 CV-CONEBUTE3 CVEC 95% 115 6.3 5.9 5.9 528109 CV-LAKEWOOD3 CVEC 95% 115 3.2 3.2 3.2 528116 CV-IRISHHIL3 CVEC 95% 115 4.1 3.8 3.8

Sum of Projected Substation 121.0 118.3 118.3

Loads

121.0 118.3 118.3

INTERRUPTIBLE LOAD Need breakdown by substation of amount of load that is interruptible

Delivery Point Voltage 2009 2010 2010 Apr

SPP Bus# Substation Bus Name Min Ownership (kV) (MW) (MW)

(MW} 527514 CV-PINE 2 CVEC 69 527589 CV-ORCHARD 2 CVEC 69 527626 CV-DEXTER 2 CVEC 69 527650 CV-HAGERMAN2 CVEC 69 527657 CV-LAKARTHR2 CVEC 69 527664 CV-CTTNWOOD2 CVEC 69 527692 CV-YO 2 CVEC 69 527754 CV-ARTESIA 2 CVEC 69 527763 CV-W ARTSIA2 CVEC 69 527821 CV-DAYTON 3 CVEC 115 527828 CV-12MH 3 CVEC 115 527943 CV-LUSK 2 CVEC 69 1.4 1.4 1.4 528003 CV-DAGGR&IH2 CVEC 69 528076 CV-WAL TCYN 3 CVEC 115 528079 CV-CONEBUTE3 CVEC 115 528109 CV-LAKEWOOD3 CVEC 115 528116 CV-IRISHHIL3 CVEC 115

TOTAL INTERRUPTIBLE LOAD 1.4 1.4 1.4

TOTAL LOAD - Fall 119,6 116.9 116.9

RURAL ELECTRIC COOPERATIVES

ANNUAL REPORT

OF

CENTRAL VALLEY ELECTRIC COOPERATIVE, INC.

TO THE

NEW MEXICO

PUBLIC REGULATION COMMISSION

FOR THE

YEAR ENDED DECEMBER 31, 2009

Line

No.

Note

ldent.

0 T

w lss

hom

ued

1 18260 R us 2 1B264 R us 3 ML0632T2 COB ANK 4 1B265 R us 5 1B270 R us 6 ML0632T3 COB ANK

7

8

18272

1B280

R

R

us us

9 ML0632T4 COB ANK iO 1B283 R us 11 1B290 I R us

I 12 ML0632T5 :cOB ANK

13 1B295 R us 14 1B300 R us 15 ML0632T6 COB ANK

16

17

18305

18310

18 ML0632T1

19

20

1B315

1B320

R

R

us us -·

R

R

..

us us

21 ML0632T8 COB ANK

22 1B325 R us 23 1B330 R us 24 ML0632T9 COB ANK

25

26

27

28

29

30

31

32

33

34

35

1B331

1B332

1B340

1B341

R

R

R

R

us us us us

PUC

Decision

No.

--------

f------'- .. ._ __

Date of

Issue

---------

07/03/1973

06/01/1981

06/29/1981

08/10/1981

06/27/1983

01104/1984

06/18/1984

08103/1987

10103/1990

1Ulll.111::!l.lU

02/27/1995

0510211995

08/14/1995

01/13/1997

0112111998

10/07/1998

1212911999

08/03/2000

08/31/2000

10/1712002

11/05/2002

04/17/2003

08/04/2005

05/03/2007

12105/2008

01/2912009

03/05/2009

03/16/2009

LONG TERM DEBT (Accounts 221-228)

Date of

rlty Matu

35 ye ars

ars

ars

ars

ars

ars

ars

ars

ars

ars

lll'S

ars

ars

lll'S

lll'S

ars

ars

lll'S

ars

ars

ars

lll'S

ars

ars

ars

ars

ars

ars

35 ye

35 ye

35 ye

35 ye

35 ye

35 ye

35 ye

35 ye

35 ye

35 ye

35 ye

35 ye

35 ye

35 ye

35 ye

35ye

35ye

35 ye

35ye

35 ye

35 ye

35 ye

35 ye

35ye

35ye

35ye

35ye

Prlncipal Amount

-----·

239,000.00

58,500.00

148,000.00

297,500.00

1,295,000.00

1,110,000.00

1,295,000.00

1,713,500.00

1,469,000.00

1,713,500.00

1,547,500.00

1,327,000.00

1,547,500.00

1,481,000.00

1,269,000.00

1,481,000.00

2,886,000.00

2,474,000.00

2,886,000.00

2,612,000.00

2,239,000.00

2,612,000.00

5,352,604.00

7,298,000.00

2,748,000.00

2,604,604.00

3,163,000.00

3,161,792.00

AMOUNT OUTSTANDING

Principal Deferred Interest

0.00

15,465.21

35,191.75

78,647.83

544,803.63

484,247.29

544,803.63

979,102.05

834,330.91

1,006,962.67

1,170,611.08

743,924.26

1,170,611.08

810,546.40

1,070,114.18

846,886.58

2,334,673.37

2,263,406.83

2,336,629.10

2,257,080.27

2,084,164.67

2,246,035.78

4,935,270.56

7,026,956.13

2,676,039.66

2,536,835.77

3,096,185.28

3,095,002.78

INTEREST FOR

For YEAR

Balance Sheet

Rate Amount

0.00 5.000% 0.00

15,465.21 5.000% 861.24

35,191.75 **3.74% 1,542.96

78,647.83 5.000% 4,379.91

544,803.63 5.000% 28,664.06

484,247.29 **3.74% 19,459.781

544,803.63 5.000% 28,664.06!

979,102.05 5.000% 50,464.21

834,330.91 **3.74% 32,839.76

1,006,962.67 5.000% 51,890.89

1,170,611.08 5.000% 59,513.85 ·

743,924.26 **3.74% 29,171.63.

1,170,611.08 5.000% 59,513.85

810,546.40 3.500% 29,093.53

1,070,114.18 ***4.84% 52,022.53

846,886.58 1.125% 27,924.32 •

2,334,673.37 3.750% 88,738.13

2,263,406.83 ***6.06% 140,216.58

2,336,629.10 3.500% 82,930.35

2,257,080.27 1.125% 73,455.69

2,084,164.67 ***3.57% 106,542.77

2,246,035.78 2.750% 62,607 51

4,935,270.56 2.750% 137,350.35

7,026,956.13 ···s.95% 346,783.93

2,676,039.66 1.625% 47,287.39

2,536,835.77 1.125% 26,652.98

3,096,185.28 1.125% 29,091.77

3,095,002.78 1.125% 28,008.69

36

37

38

················--···--·--- ___ Total ------······-·--- _______________ 47,224,528.75 0.00 47,224,528.7 __ 5-1----- 1,645,672.72

-·L_!:i-S: Advance Payments Unapplied-Account.224.6 ... (4,591,085._48-+--- ___ (4,_59_1_,_08_5_.4_8....__ ___ ---<-----<

------------···········--·-····------------~-----+--Total 42,633,443.27 0.00 42,633,443.27 1,645,672.72

·······--·-··--· ----~:-'l!!.~~ge on variable rate! mortgage •••fixed rate

··-·--·····-----

ELECTRIC OPERATION AND MAINTENANCE EXPENSES 1. Enter in the space provided the operation and mainte- 2. If the increases and decreases are not derived from pre-

nance expenses for the year. viously reported figures explain in footnotes. ,-----~ ----"--------------~~-! --

i Line No.

Increase or Account Amount for year decrease from

1 (a) (b) preceeding year

L ___ J ~-----------------+-----------+-~-__,_(c__,) ___ ____J

1 POWER PRODUCTION EXPENSES $ $ 2 STEAM POWER GENERATION 3 OPERATION

4 500 Operation supervision and engineering

5 501 Fuel

6 502 Steam expenses

7 503 Steam from other sources

8 504 Steam transferred-Cr.

9 505 Electric expenses

10 506 Miscellaneous steam power expenses

11 507 Rents i 12 Total operation N/A N/A

13 Maintenance

14 ! 510 Maintenance supervision and engineering 15 511 Maintenance of structures

16 512 Maintenance of boiler plant 17 513 Maintenance of electric plant

18 514 Maintenance of miscellaneous steam plant 19 Total maintenance N/A N/A ____ ,___

20 Total power production expenses-steam power N/A N/A ----+------------->

21 NUCLEAR POWER GENERATION

22 Operation :

23 517 Operation supervision and engineming I

24 518 Fuel

25 519 Coolants and Water

26 520 Steam expenses

27 521 Steam from other sources

28 522 Steam transferred-CR ( ) ( )

29 523 Electric expenses

30 524 Miscellaneous nuclear power expenses

31 525 Rents

32 Total Operation N/A : N/A I

33 Maintenance

34 528 Maintenance supervision and engineering

45 529 Maintenance of structures

36 530 Maintenance of reactor plant equipment 37 531 Maintenance of electric plant

38 532 Maintenance of miscellaneous nuclear plant '

39 Total maintenance N/A i N/A

40 Total power production expenses-nuclear power N/A N/A 41 HYDRAULIC POWER GENERATION 42 Operation 43 535 Operation supervision and enginee,ring 44 536 Water for power 45 537 Hydraulic expenses 46 538 Electric expenses 47 539 Miscellaneous hydraulic power generation expenses 48 540 Rents 49 Total operation N/A N/A

···--·-· 50 Maintenance 51 541 Maintenance supervision and engineering 52 542 Maintenance of structures

----------------------------------------· "------·····-·····-· ·····-··--· ---------,

Line No,

ELECTRIC OPERATION AND MAI.N .TENA _N_C

1~ EXPENSES (Continued)

Account Amount for year (a) (b)

1

2 3

4

5

6

7

8

HYDRAULIC POWER GENERATION (Continued) 543 Maintenance of reservoirs, dams and waterways

544 Maintenance of electric plant

545 Maintenance of miscellaneous hydraulic plant

Total maintenance

Total power production expenses-hydraulic power

OTHER POWER GENERATION

Operation 9 546 Operation supervision and engineering 10 547 Fuel

11 548 Generation expenses

12 549 Miscellaneous other power generc,tion expenses

13 550 Rents

$ $ i

i I

•-·--·

N/A

i N/A I ' I

Increase or decrease from

preceeding year (c)

N/A N/A

i

,.. ····--------------+-------------------, 14 Total operation 15 Maintenance



18 553 Maintenance of generating and elec1nc plant

19 554 Maintenance of miscellaneous other power generation plant

20 Total maintenance

21 Total power production expenses-other power

22 OTHER POWER SUPPLY EXPENSES

23 555 Purchased power

24 556 System control and load dispatching . 25 557 Other expenses

• 26 Total other power supply expenses

27 Total power production expenses

28 TRANSMISSION EXPENSES

29 Operation 30 560 Operation supervision and engineering

31 561 Load dispatching 32 562 Station expenses

33 563 Overhead line expenses

34 564 Underground line expenses 35 565 Transmission of electricity by others

36 566 Miscellaneous transmission expense·s

37 567 Rents

i 38 Total operation

139 Maintenance

, 40 568 Maintenance supervision and engi 1eering


: 42 570 Maintenance of station equipment '43 571 Maintenance of overhead lines 44 572 Maintenance of underground lines 45 573 Maintenance of miscellaneous trar 1srnission plant 46 Total maintenance 47 Total transmission expenses 48 DISTRIBUTION EXP ENSES 49 Operation 50 580 Operation supervision and enginee ffing 51 581 Load dispatching 52 582 Station expenses 53 583 Overhead line expenses 54 584 Underground line expenses 55 585 Street lighting and signal system e: <penses

----·--·· ~--

N/A

N/A

N/A

29,951,429.15

29,951,429.15

29,951,429, 15

7,477.08

47,775,00

55 252 08

0,00

0,00

0,00

55,252,08

126,095,92

87,071,96

530,633.45

14,417,521

I ..

N/A

NIA

N/A

( 15,411,843,94

(15,411,843.94 ~

(15,411,843.94)

1,777.54

10,019,78

11 797 32 '

0,00

0,00

0,00

11,7-~_I,32

(19,230,98

3,944.42

(80,956,65! 2,952,39

I

ELECTRIC OPERATIC)~~ AND MAINTENANCE EXPENSES (Continued)

Line No. Account

(a)

2

3

4

5

6

7

DISTRIBUTION EXPENSES (Continued)

586 Meter expenses

587 Customer installations expenses

588 Miscellaneous distribution expenses

589 Rents

Total Operation

Maintenance



10 592 Maintenance of station equipment

11 593 Maintenance of overhead lines

12 594 Maintenance of underground lines

13 595 Maintenance of line transformers

14 596 Maintenance of street lighting ancl signal systems

15 597 Maintenance of meters

16 598 Maintenance of miscellaneous distribution plant

17 Total maintenance

18 Total distribution expenses

19 CUSTOMER ACCOUNTS EXPENSES

20 Operation

21 901 Supervision

22 902 Meter reading expenses

23 903 Customer records and collection expenses

24 904 Uncollectible accounts

25 905 Miscellaneous customer accounts expenses

26 Total customer accounts expensEls

27 SALES EXPENSES

28 Operation

29 907 Supervision

30 908 Customer service information expenses

31 909 Advertising expenses & consumeI· information

32 910 Misc. customer information expenses

33 912 Demonstrating and selling expenses

34

Total sales expenses 45

36

37

38

39

40

41

42

43 44 45 46 47 48 49 50 51

52 53 54 55

ADMINISTRATIVE AND GENEHAL EXPEN SES

Operation

1920 Administrative and general salaries

921 Office supplies and expenses

922 Administrative expenses transferred-Cr.

, 923 Outside services employed

, 924 Property insurance

925 Injuries and damages 926 Employee pensions and benefits 927 Franchise requirements 928 Regulatory commission expenses 929 Duplicate charges-Cr. 930 Miscellaneous general expenses 931 Rents

Total operation MaintenancE1

932 Maintenance of general plant Total administrative and general expense Total Electric Operation and Maintenance Exp enses

$

Amount for year (b)

128,278.50

11,594.04

40,968.68

0.00

939,060.07

241,400.83

1,270,524.38

9,756.18

32,181.43

0.00

223,256.33

27,670.79 i

$

Increase or decrease from

preceeding year (c)

-----

(59,969.99

242.52

(4,349.72 0.00

(157,368.01

------------- ~---

---

·-

1,804, 789.94 '

2,743,850.01

i 78,972.71 I

339,133.95 i

453,015.68 •

19,000.00.

0.00.

890,122.34 •

0.00

122,946.16

17,968.35

0.00

86.961

141,001.47'

812,180.61

108,571.35

0.00

528,837.54

0.00

68,619.03 0.00 0.00

285,901.10 (18,355.89 434,650.82

19,925.81 2,240,330.37

39,416.76 2,279,747.13

36,061,402.18

(56,818.44

(214,186.45

2,318.63

5,804.12

55,982.97

19,000.00

0.00

83,105.72

(48.66~ 53,572.721

(665.99) 0.00

(3,963.04 ~

48,895.03

188,235.55

11,678.78

0.00

197,096.22

0.00

35,311.15 0.00 0.00

43,938.90 6,632.43

14,857.43 (1,555.33

496,195.13

580.34

496,!~5.47 (14,985,456.85

Line · No.

1

2

3

4

5

6 7

8

9

10

11 12

13

14

Page 4

ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued)

SUMMARY OF ELECTRIC OPERATION AND MAINTENANCE EXPENSES

Functional Classification (a)

Power Production Expenses Electric Generation:

Steam Power

Nuclear power

Hydraulic power

Other power

Other power supply expenses

Total power production expenses

Transmission Expenses Distribution Expenses Customer Accounts Expenses Sales Expenses Adm. and General Expenses

Total Electric Operation and Maint,,mance Expenses

$

Operation (b)

29,951,429.15

29,951,429.15

55,252.08

939,060.07

890,122.34

141,001.47

2,240,330.37

34,217,195.48

Maintenance (c)

$

0.00

1,804,789.94

39,416.76

1,844,206.70.

$

Total (d)

29,951,429.15

29,951,429.15

55,252.08

2,743,850.01

890,122.34

141,001.47.

2,279,747.131

36,061,402.18

NUMBER ELECTRIC DEPARTMENT EMPLOYEES

Number of electric employees, period ended

1. Total regular full-time employees

2. Total part-time and temporary employees

3. Total employees

The data on number of employees should be reported for the

payroll period ending nearest to October 31, or any payroll

period ending 60 days before or after October 31.

If the respondent's payrolls for the reported period include

any special construction forces include such Hrnployees as part

time and temporary employees and show the number of such

10/31/2009

66 0

66

special construction employees so included.

The number of employees assignable to the electric depart

ment from joint functions of combination utilities may be de

termined by estimate, on the basis of employee equivalents.

Show the estimated number of equivalent employees attributed

to the electric department from joint functions.

Designation of Area

(Primary substation,)

operating division,

or communityj

Systemwide

Map

Page 5 -------------------------~

DISTRIBUTION OF SYSTEM LOAD IN SERVICE AREA

1. Information is desired regarding the distribution of the system load within the territory served by the system. This information

should be furnished on the basis used by respondent in maintaining load distribution data, such as by primary substations, operating

divisions, communities, metropolitan areas, or other areas.

2. A sketch map showing the location and the approximate boundary of each of these areas, together with identification symbols,

should be furnished.

-----------------~----- --~---,----

Total

______ Annual Energy Provided for the Area-----------~

Estimated Distribution - Percent --------------- ----------------~-

Public Streets Other Sales

Residential Commercial Industrial and Highway to Public Irrigation Cnmp~ny IJr-.accounted

Actual or Estimated

Peak Demand of

Area During the

Year

Annual

Date of Load

Symboi {Kiiowatt-hoursj Saies Lighting Authority Sales Use For (Kilowatts) Peak Factor

763,61 8.17% 11.46% 0.00% 8.13% 0.05% 7.41% 1 06, 509 08/09 7

Area I rm tion ot Availa le

-------------------------------'------'---------------------------- -----------'----- -----'---------------- ------- .. --------··--'---------------- ············-- ················--·'----~--~

__ CONSTRUCTION OVERHEADS-ELECTRIC

1. Report below the information called for concerr ing construction overheads for the year.

2. List in column (a) the kinds of overheads accor,jing to the titles used by the respondent. Charges for outside profe ,sional services for engineering fees and management of supervision fees capi

talized should be shown as separate items

3. On the lower section of this schedule furnish the requests,

explanatory information concerning construction overheads. 4. A respondent should not report "none" to this schedule if

no overhead apportionments are made, but rather should explain on

the lower section of this schedule that only such engineering, supervisor, and administrative costs. etc., which are directly chargeable

construction are charged to construction, if this is the case. Engineering, supervision, administrative, and interest costs, etc., which

are first assigned to a blanket work order and then prorated to con

struction jobs shall be considered overheads for the purposes of formulating a response to this schedule.

June Name of Overhead Total overheads cleared Cost of construction to which Percent overheads I overheads were charged (ex-) No. lo construction construction cost ' elusive of overhead charges)

(a) (b) (c) Indirect Labor& Associated Payroll Taxes $191,439.59

2 Employee Benefits 3 Transportion 4 Depreciation on Equipment 5 Miscellaneous 6 Transformer Installation 7 Accounts Payable 8 Property Insurance & Taxes 8,398.68 9 Clearing of overhead account into construction 300,198.46 10 during software conversion. Due to process 11 change.

TOTAL $1,021,079.99 7.15

GENERAL DESCRIPTION OF CONSTRUCTION OVERHEAD PROCEDURE

1. For each construction overhead for electric plant explain

(a) nature of the engineering, supervisory, or administrative work, etc., the overhead charges are intended to cover. (b) the general procedure for determining the amount capitalized. (c) the method of distribution lo construction jobs. (d) percentages applied to dif

ferent types of construction. (e) basis of differentiation in percentages for different types of construction, and (f) amounts capital

ized for each overhead for the year for which this report is submitted.

2. In addition to other information concerning engineering and superintendence or other such overheads, explain whether the

amounts treated as overheads include all engineering and superintendence costs or only such portions as are not directly chargeable to specific jobs.

3. For interest during construction state the interest rate used, the basic charges to which applied, in addition to the amounts

capitalized for the year for which this report is submitted.

Indirect Labor, Accrued Vacation, Accrued Sickleave, Employee Etc. Are Prorated to Construction On The Basis Of Direct Labor Charged to Construction.

(d)

13.38% 6.10% 2.23%

-0.01% -7,65% 0.88% 0.24% 8.60%

29.26%

Stores Expense & Expendable Material Overhead Is Determined by the Percentage Of Material Issued Directly To Construction On A Monthly Basis.

____E§gi3 7 - --ELECTRIC DISTRIBUTION METERS AND LINE TRANSFORMERS

1. Report below the information called for concerning distri

bution watt-hour meters and line transformers.

1 2. Watt-hour demand distribution meters should be included

below but external demand meters should not be included.

3. Show in a footnote the number of distribution wait-hour

meters or line transformers held by the respondent under lease

from others, jointly owned with others, or held olher,vise than

by reason of sole ownership by the respondent. If 500 or more

Line Item No.

(a)

Number at beginning of year

2 Additions during year:

3 Purchases

4 Associated with utility plant acquired

5 Total additions

,6 Reductions during year:

7 Retirements

8 Associated with utility plant sold

9 Total reductions

10 Number at end of year

11 In stock

12 Locked meters on customers' premises

13 Inactive transformers on system

14 In customers' use

15 In company's use

16 To_!_al end of_year (as above)

meters or line transformers are held under a lease, give name of

lessor, dale and period of lease and annual rent. If 500 or more

meters or line transformers are held other than by reason of sole

ownership or lease, give name of co-owner or other party, ex

plain basis of accounting for expenses between the parties, and

state amounts and accounts affected in respondent's books of

account Specify in each case whether lessor, co-owner or other

party is an associated company.

LINE TRANSFORMERS

Number of watt-hour Number Total capacity (kva) meters

(b) (c) (d)

1},59i3~_ ~0,844 1,098,343.1 ,

1,513 640 44,931.5

0 0 0.0

1,513 640 44,931.5

402 84 1,196.0 i

0 0 0 402 84

14,707 21,400~_ 1_, 142,0?t:3.13_

1,350 1,017 359,801.5'

425

508 8,348.0

12,825 19,806 472,049.1 1

i

107 69 301,88Q.O 1

14,707 21,400 1,142,078.6 ·

__ P_age8 -----------------------------------

VERIFICATION

The foregoing report must be veirified by the oath of the office having control of the accounting of the · respondent. The oath required may be taken before any person authorized to administer an oath by the laws of the State in which the same is taken.

OATH (To be made by the officer having control of the accounting of the respondent.)

State of New Mexico ss:

• County of Eddy

Mike Anderson makes oath and says that he is Assistant Manager (Insert here the official title of the affiant.)

of Central_valley Electric Cooperative, l_nc_. __ _ ( Insert here the exact legal title of the respondent.)

that it is his duty to have supervision over the books of account of the respondent and that to the best of • his knowledge and belief such books have, during the period covered by the foregoing report, been kept• in good faith in accordance with the accounting and other orders of the New Mexico Public Regulation Commission, effective during said period, that has examined the said report, and to the best of his knowledge and belief the information contained in the said report is, insofar as it relates to matters of account, in accordance with the said books of account; that he believes that all other statements of fact contained in the said report are true, and that the said report is correct statement of the business and affairs of the above-named respondent in respect to each and every matter set forth

therein during the period from and including

to and including

Subscribed and sworn to before me, a

County above named, this 28th

My commission expires

JANUARY 1 ------

DECEMBER 31

~ U~re of affiant)

__ n_otary , in and for the State and

day of APRIL , 2009. -----------

_____________ May_25,_2013

, 2009.

, 2009.

............. _!~~{!HL -· ignature of offic~itHorized to administer oaths.)

-· ·-------- -·----·------ -------

New Mexico Jurisdictional Information Year Ending December 31, 2009

Electric Company Name Central Valley Electric Cooperative, Inc.

Address: P.O. Box 230 Artesia, NM 88211-0230

Phone Number: 575-746-3571 -----------------

Person Completing Form: GLENDA GIDEON

Customer Class Residential Other

Number of Customers 5,097 7,713

KWH Sales 60,386,953 646,210,359

Gross Revenues $4,247,099.02 $39,480,205.12

Avg. Annual KWH per Customer ( 1) 11,8+- 83,782

Avg. Annual Bill per Customer (2) $833.25.

Avg. Monthly Bill per Customer (3) $69.441

! Avg. Gross revenue per KWH sold (4) $0.070331

Directions for the completion of (1 ), (2), (3), (4):

(1) Divide KWH sales by number of customers.

(2) Divide gross revenues by number of customers.

(3) Divide (2) by 12 months ..

(4) Divide gross revenues by KWH sales.

NMPRC Rule 510

$5,118.66

$426.55

$0.061095

FORM 1

Total

12,810

706,597,312

14

60

$3,413.53

$284.46

$0.061884

Effective 01/01/89

CENTRAL VALLEY ELECTRIC COOPERATIVE, INC. P. 0. Box 230 - 1505 North 1 :3th Street Artesia, NM 88211-0230

NMPRC Rule 510.4(b)->17.3.510 .. 12(B) NMAC

PERIOD ENDING RATE CASE 12/31/09 2008

(A) Revenues $45,911,865 $66,720,279

(B) Earnings $5,581,542 $3,800,000

(C) Return on Equity (or margin) 7.6852% 5.7376%

(D)(E) Capital Structure 1. Debt $42,633,443 $33,752,943 2. Margins $43,892,403 $39,161,584 3. Debt as a Percent 49.3% 46.3% 4. Equity as a Percent 50.7% 53.7% 5. Average Cost of Debt 3.860% 4.440%

(F) Generation Plant-in-Service including for each plant: None None

(G) Transmission and Sub-transmission Pliant in Service $8,914,915 $8,552,653 General Plant in Service $5,731,653 $5,224,183

(H) Distribution Plant in Service $71,808,771 $67,030,353 Total Plant in Service $86,455,339 $80,807,189

(I) Operation & Maintenance Expense: Purchased Power $29,951,429 $51,867,165 Operation & Maintenence Expense $6,109,973 $8,879,286

Total Operations & Maintenance Expense $36,061,402 $60,746,451

(J) Deferred Tax Reserves None None

(K) Peak Demand - KW 106,509 115,436

(L) Net Energy Sales - KWH 706,597,312 736,869,194

P'oocur.cling to: tbc :Wayrt!T.WQlfi R:edtOC"1ion Act of 1995. an agency may not conduct or sponsor_ and a person is not required to respond to, a collection of infonnation unless it displays a valid 0MB ~nntmll mun!,,,,,. IDie: valadl 0MB ""'"""I numocr for this infonnation collection is 0572-0032. The time required to complete this infom,ation collection is estimated to average 16 hours per r~sp-ouse. int:1Ucling tire· riiw:~ fotr rt.."'\,"kv.-ing instructions. searching cxi>ti11g data sources. gathering and maintaining the data needed. and completing and reviewing the coilecnon of infon1iation,

1UNllTIEDSIATESDEPARTMENTOF AGRICULTURE BORROWER DESIGNATIO~ NM0004 RURAL UTILITIES SERVICE

PERIOD ENDED

FINANCIAL AND ST A TISTICAL REPORT December, 2009

JINSliliUJCTllONS - lfov d'daikd instructions, see RUS Bulletin 1717B-2. BORROWER NAME

7!1ris di:JJJJa:TJ11iPU !!Hi!" u1setl.i 1/JJr RUS lo rt-i-ieir your financial s1tuafion Your response is CENTRAL VALLEY ELEC COOP INC req11ired f 7 U.S C '~IN et. seq) a11d may be confidential.

CERTIFICATION

11\'t r«og111izc- U1a1 starrments contained herein conc,eni a matter within the jurisdiction of an agency of the llniled States and the making of a fal:H·, fidiliolll$ or frand111h,nt statement may render the maker subject to prosecution under Title 18, linited States Code Section 1001.

We ~· o."111iJy !hat the entries in this rep011 are in accordance with the accounts and other records of the system and reflect the status of the system to !he best of oor ll;Jmowledge and belief.

ALI, 1s~-URA"IIC£ REQURED BY PART 1788 or 7 CFR CHAPTER XVII, RlJS, WAS IN FORCE DURING THE REPORTING PERIOD AND llt'.\(E\\'AL~ ILU"E BEEN OBTAl"IED FOR ALL POLICIES

DFRl1'G THE PERIOD COVERED BY THIS REPORT Pl1RSUANT TO PART 1718 OF 7 CFR CHAPTER XVII (check one of the fo/lowi11g)

m All of the obligations under the RUS loan documents • There has been a default in the folfillment of the obligations

have been fulfilled in all material respects. under the RUS loan documents. Said default( s) is/arc specifically described in Part D of this report.

Charles Pinson 3/17/2010

DATE

PART A. STATEMENT Of OPERATIO'IS

YEAR-TO-DATE ITEM LAST YEAR THIS YEAR BUDGET THIS MONTH

(a) <b) /c) <d) L Operating Revenue and Patronage Capital 56,501,997 45,911,865 64,096,842 4,026,093 2, Power Production Exnense 0 0 0 0

3. Cost of Purchased Power 45,363,273 29,951,429 47,702,337 2,694,238

4. Transmission Expense 43,455 !:5,252 48,698 4,604 s. Distribution Expense - Operation 1,096,428 939,060 1,141,607 91,625 6, Distribution Expense - Maintenance 1,861,608 1, sc,4, 790 1,880,416 202,440 7, Customer Accounts Expense 807,017 890,122 876,683 70,404 8. Customer Service and lnfomiational Exoensc 88 056 14 0 915 93 852 l" .;Ac;

9. Sales Expense 4,050 87 4,788 0

10. Administrative and General Expense 1,782,972 2,279,747 1,906,877 222,661 11. Total Operation & Maintenance Expense (2 thru JO) 51,046,859 36,061,402 53,655,258 3,300,657 12. Depreciation and Amortization Expense 2,466,997 2,6J.4,023 2,588,375 221,554 n Tax Expense - Property & Gross Receipts 0 0 0

14. Tax Exnense - Other 369 373 390 0

15. Interest on Lonir-Term Debt 1,552,500 1,645,673 1,835,179 130,142 16. Interest Charged to Construction - Credit 0 0 0 0

17. Interest Expense - Other 4,296 2,032 2,800 138

18. Other Deductions 21,039 6,820 20,000 250 19. Total Cost of Electric Service(/ I thru I 8) 55,092,060 40,330,323 58,102,002 3 652 741 20. Patronage Capital & Operating Margins (1 minus 19) 1,409,937 5,SBl,542 5,994,840 373,352 21. Non Operating Margins - Interest 390,755 4B6,822 400,000 42,978 22. Allowance for Funds Used During Construction 0 0 0 23. Income (Loss) from Equity Investments 0 0 0 24. Non Operating Margins - Other 0 0 0 25. Generation and Transmission Capital Credits 0 0 0 26. Other Capital Credits and Patronage Dividends 125,556 148,766 100,000 0 27. Extraordinarv Items 0 0 0 28. Patronage Capital or Margins (20 thru 27) 1,926,248 6,217,130 6,4:l4,840 416,330

RUS Fonn 7

lJ',[);\ - RlJS

FINANCIAL AND STATISTICAL Rl:PORT

l"ISTRUCTIO"-S - Sec RUS Bulletin l 7 l 7B-2

BURRO\\l:R DLSl(iN1\ I 101\

NM0004

PIRIO!l END FD

December, 2009

P.\RT B. DA'L\ O', TR.\',S'.\IISSIO'\ \'.\D DISTIUBI TIO'\ PLA'\'T

\L\R-TO-D.\TE \E.\R-TO-D,.\TE

ITE'.\1 L\ST\EAR TIIIS YEAR

(a) (b) ITEM LAST \EAR TIIIS \EAR

(a) (b)

I. New Sen i.:es Connected 447 361 5. Miles Transmission 1"l 2. 00 132.00

2. Servi.:es Retired

3. l"otal Services in Place

4. Idle Services (/;\c/11de .\ea,ona/s)

73

16,361

3, 814

6. 34

7. 16,688

8. 3 / 86 3

Miles Distribution -O\·erhead

3,736.00 3,766.00

Miles Distribmion -Underground

25.00 25.00

Total Miles Energized (5 - 6 71 3,893.00 3,923.00

PART C. B.\L.\:\O: SIIEET

.\SSETS \:\D OTIIER DEBITS

I. Total Utility Plant in Service

2. Construction Work in Progress ............................. .. 3. fotal Utility Plant ( I 2! 4. A.ccum. Provision for Dcpn:eiation and Amor! 5. Net Utility Plant r3 - ./.1 6.

7. Non-Utility Property (Net) ................................ ..

Im cstments in Suhsidiary Companies ................. .

86,455,339

4,514,532

90,969,871

21,946,220

69,023,651

0

0

8. lnn:st. in AssPc. Org. - Patronage Capital ............. ______ 5_4_9_, _3_3_6

9. Invest. in Assoc. Org. - Other - (jeneral Funds ...... o 10. lmcst. in Asso<.:. Org. - Other- Nong,~neral Funds .. _______ o

11. lmestm<.:nts in Economic Devclnpment Projects.... o 12. Other Investments .................................................. 1 688

13. Special Funds ............. ............................... o 14. Total Other Property & Investments (6 thl'II 13! 551,024

15. Cash General Funds .............................................. s, 2 J B, 3 71 --------

16. Cash - Construction Funds - Trustee · · · · · · · · · · · · · · · · · · · · · 0 17. Special Deposits ...................... .. 18. Temporary Investments .................................. .. I 9. Noks Recei\·able (Net) ................................... .

------------

0

--~]3~, 7~9_7__,_. 04 _s_ 249,022

20. A<.:counb Receivable - Sales of Energy (Net) .......... ···························2·········6····8····8·········9·····9····8···· 21. Accounts Reeei,·ahlc - Other ( Net) ........................ _____ 5_9_,_2_7_3

22. Materials and Supplies Electric & Other _________ 2~_2_s_s_,_~_2-~_

23. Prepayments .......................................... .. 24. Other Current and Accrued Assets ............. .. 25. ·fotal Current and Accrued Assets ( I 5 ihl'll ]./) 26. Regulatory Assets 27. Other Deferred Debits 28. Total Assets and Other Debits 15 l-1- .:'5 thru :!7J ..

RUS I ORM 7

84,257

6,477

27,378,565

0

(728, 080i

96,225,160

U\BILITIES ,\:'\D OTIIER CREDITS

29. Membership,.... .. ............. . 0

30. Patronage Capital. ...................................................... ___ 3_7-'--, _3_0_4-'-, _3_8_1

JI. Operating :Vtirgins Prior Years... 288,272

32. Operating Margins - Cu1Te11t Year. 3, 7 3 o, 3 OB

J3. N(in-Opcrntmg Margins....................... 686,209

34. Other ;\-fargins and Equities.......... (116,767)

35. Total Margins & Equ1tie, (29 1hr11 3./J.. 43,892,403

36. Long-'lennDebt-RUS(Net).................... 31,624,193

37. Long-Tm11 Dcht - FFB - RLS Guaranteed. o :l8. Long-Term Debt - Other - RUS Guaranteed .............. ________ o 39. Ln11g-Tcm1DcbtOthcr(Nct)..................................... 14,542,336

40. Long-Term Debt - RUS - Econ. DeYel. (Net) ............. ________ o 41. l'aymcnts-Unapplicd 4,591,086

42. Total Long-Term Debt r315 thru ./IJ- -1/J.. 41,575,443

43. Obligations Under Capital Leases - '\Joncurrcnt.. ....... ___ _ 0

44. Accumulated Operating Provisions and Asset Rdin:mcnt Obligations.. .. .................... _____ 4_0_3_,_6_9_1

45. Tt>tal Other N"ncurrent t iabilities / ./3 ././J. 4 O 3, 6 91

46. Notes Payable ................................................. --------'--o

47. Accounts Payable....................................................... 3,168, 7S.S

48. Consumers Deposits.................................................. 100,567

49. Current Maturities LPng-Tcrm Debt................ 1,058, ooo 50. Current Matuntics Long-Term Debt

-Ee\momic De\ clopment.. .................. .

51. Current \1aturitics Capital Leases ...... .

52. Other CmTent and Accru.:d Liabilities ...................... .. 53. Total Current & Accrued Liabilities (./6 1hm 5:!). 54. Regulatory Liabilities ............................................... ..

55. Other Defcmxl Credits ................................. .. 56. Total Liabilities and Othu Credits

(35 · 12 ./5 53 lhru .'51 ..

0

0

6,982,834

0

3 370 789

96,225,160

U3DA-RUS BORROWER DESIGNATION

NM0004

FINANCIAL AND STATISTICAL REPORT PERIOD ENDED

December, 2009

INSTRUCTIONS - See RUS Bulletin 1717B-2

PART D, NOTES TO FINANCIAL STATEMENTS

RUS Form 7

l ~IJ;\ - l{l.lS BORROWl:R l>J--;fGNAl 101\

FINANCIAL AND STATISTICAL REPORT Pl:RIOD l::NDED

INSTRUCTIONS - Sec RlJS Bulletin 17178-2

PART E. CHA:\GES IN FHLITY PL\:\'T

BALANCE ADJUSTMENTS BALANCE END BEGINNING ADDITIO;'IIS RETIREMENTS AND TRANSFER OF YEAR

PLANT ITEM OF YEAR (al (h) (<') (dl (e)

I. Distribution Plant 68,797,646 6,352,628 3, .l4 l, 503 71,808,771

2. General Plant 3,498,921 573,886 452,853 3,619,954

3. Headquarters Plant 2,110,826 873 2,111,699

4. Intangibles 0 0

5. Transmission Plant 8,898,130 24,656 7,871 8,914,915

6. All Other Utility Plant 0 0

7. Total Utilitv Plant in Service ( I thru 6) 83,305,523 6,952,043 3,802,227 86,455,339

8. Construction Work in Progress 1,348,371 3,166,161 4,514,532

9. TOTAL UTILITY PLANT (7 ii) 84,653,894 10,118,204 3,f302,227 90,969,871

P.\RT F. \l\TEHL\LS .-\'.'iD Sl PPUES

BALANCE BALANCE ITEM BEGIN:\il'.\G Of PURCHASED SALVAGED USED (NET) SOLD ADJUSTMENT END OF YEAR

YEAR <a) (h) (c) (d) (e) (/) (g)

I. Electric 2,067,166 2,052,906 139,232 2,248,320 12,878 257,016 2,255,122

2. Other 0 0

PART G. SElfflCE l:\TERRl PTIO:\'S

ITEM AVF.RAGF MINLTES PER CONSUMER BY CAUSE TOTAL POWER SUPPLIER 'vfAJOR EVENT PLANNED ALI. OTHER

(a) lh) (cl (d) (e)

I. Prcs,,nt Y car .050 1.000 .020 6.200 7.270

2. Fivc-YcarAvcrage 13.910 12.420 .220 20.350 46.900

PART II. E'.\IPLO\EE-IIOl iR.\'.'11) PA \ROLi. ST\TISTICS

I. Number of Full Time Employees 64 4. Payroll - Expensed 2,116,486

2. Employ<.."C - Hours Workt.>tl - Regular Time 136,901 5. Payroll - Capitalized 1,341,616

3. Employee - Hours Worked - Overtime 4,052 6. Payroll - Other 443,681

PART I. PATROX\GE CAPITAL

ITEM THIS YEAR CU MULA TIYf: DESCRIPTION (a) ih)

I. Capital Credits - a. Gcncrnl Retirements 1,20.5,038 15,349,042 Distributions b. Special Retirements 14,793 241,660

C. Total Retirements (a+ b) 1,219,831 151590,702

2. Capital Credits - a. Cash R<..'Cciv<..'CI From Retirement of Patronage Capital by Suppliers Ru:civc<l of Electric Power 0

b. Cash Received From Retirement of Patronage Capital by Lenders for Credit Extended to the Electric System 88,635

C. Total Cash Rcccin,xi (a+ b) 88,635

PART J. Dl E FROM CONS( lMERS FOR El,ECTRI(' SERVICE.

I. AMOUNT DUE OVER 60 DAYS I$ 99,3101 2. AMOUNT WRITrEN OFF DURING YEAR $ 45,095

IUIS Form 7

USDA-RUS BORROWER DESIGNATION

NM0004


December, 2009

INSTRUCTIONS See RUS Bulletin 1717B-2

Part K, kWh PURCHASED AND TOTAL COST

No ITEM RUS USE ONLY kWh PURCHASED TOTAL COST AVERAGE COST INCLUDED IN INCLUDED IN (a) SUPPLIER CODE (c) (d) (Cents/kWh) TOTAL COST- TOTAL COST-

(b) (e) FUEL COST WHEELING AND ADJUSTMENT OTHER CHARGES

(fl (g)

1 Southwestern Public 17718 740,617,327 29,951,429 4.04 6,278,595 0 Service Co

Total 740,617,327 29,951,429 4.04 6,278,595 0

RUS Form 7


NM0004


December, 2009

INSTRUCTIONS - See RUS Bulletin 17178-2

PART L. LONG-TERM LEASES

No NAME OF LESSOR TYPE OF PROPERTY RENTAL THIS YEAR (a) (bl (cl

1 None

Total

RUS Form 7

USDA-RUS BORROWER DESIGNATION NM0004


INSTRUCTIONS - See RUS Bulletin 17178-2 December, 2009

PART 1\1. ANNl'AL MEETING AND BOARD DATA

I. Date of Last Annual Meeting 2. Total Number of Members 3. Number of Members Present at 4. Was Quorum Present?

3/7/2009 3,743 181 y

5. Number of Members Voting by 6. Total Number of Board Members 7. Total Amount of Fees and Expenses 8. Does Manager Have Proxy or Mail for Board Members Written Contract?

0 7 $ J.50, 114 N

RUS Fonn 7

USOA-RUS BORROWER DESIGNATION

NM0004

FINANCIAL AIND STATISTICAL REPORT PERIOD ENDED

December, 2009

INSTRUCTIONS- See RUS Bulletin 17178-2

PART N. LONG-TERM DEBT AND DEBT SERVICE REQUIREMENTS

No ITEM EIAi_ANCE END OF YEAR TOTAL {a) {Billed This (Billed Year) (Billed This Year)

(bl le) Id)

1 Rural Utilities Service (Excludes RUS Economic 31.624, 193 917,093 1,000,830 1,917,923 nRvPlnnmentloans)

2 National Rural Utilities Cooperative Finance Corporation

3 Bank for Cooperatives

4 Federal Financinq Bank

5 RUS - Economic Development Loans

6 Payments Unapplied 4,591,086

7 COBANK 14,542,336 728,580 338,922 1,067,502

Total 41,575,443 1,645,673 1,339.752 2.985,425

RUS Form 7

USDA-RUS BORROWER DESIGNATION NM0004

HNANCIAL AND STATISTICAL REPORT PERIOD ENDED

11iNSRllJ(C'OONS - Sit<£' RUS Bulletin I 717 B-2 December, 2009

I PARTO. POWERREQl1lREMENTS DATA BASE-ANY,..TALSl1MMARY I I

HA.SS-lllFOCATION CONSUMER SALES & REVENUE DECEMBER AVERAGE NO. TOTAL

DATA CONSUMERS SERVED YEAR TO DATE

(a) (b) (c)

Ji .. ~ Sallies a. No. Consumers Served 5,114 5,097

. .... -.., b. kWh Sold 62,386,322

S€asomi!ll)l c. Revenue 4,494,401

2 .. JR;e~lllJllruill 5.tlles a. No. Consumers Served ~)a b. kWh Sold

c. Revenue 3 . .,.,: __ •• Sa:lle, a. No. Consumers Served 668 685

b. kWh Sold 62,107,780

c. Revenue 3,889,970

4. Coomi. and Ind. a. No. Consumers Served 7,022 6,930

I!WKVAor b. kWh Sold 323,336,055

Less C. Revenue 21,934,318

5 Comm. and Ind. a. No. Consumers Served 21 21

' Ovt.>.r IOOO KV A b. kWh Sold 258,745,759

c. Revenue 13,405,279

6. Public Street & a. No. Consumers Served 24 24

l mae,., ,,..,,._..J b. kWh Sold 21,396 Lighting

C. Revenue 3,336

7. Other Sales to a. No. Consumers Served Public Authorities b. kWh Sold

c. Revenue

8. Sales for Resale - a. No. Consumers Served

RUS Borrowers b. kwh Sold

c. Revenue

<J. Sales for Resale a. No. Consumers Served Other b. kWh Sold

C. Revenue

10. TOT AL No. of Consumers (lines 1 a thru 9a) 12,849 12,757

11. TOTAL kWh Sold (Imes lb thru 9b) 706,597,312

12. TOTAL Revenue Received From Sales of •;

Electric Energy (line 1 c thru 9c) ,.·,•;

- :, ,' ,~,,:;,. . --- 43,727,304

' --''· '" ,_ ... ,., .. , ,.-: '·· , .. "·

13. Other Electric Revenue ' ,_,•· •·.

__ :--·,;

2,184,561

14. kWh- Own Use -,•:•,ii,:,

•!·. :r:. 410,926

15. TOTAL kWh Purchase.cl >\: :;; f1 '"'':;

~:..: 740,617,327

16. TOT AL kWh Generate.cl : ·:: :~~ !'.,:.,:. :- 0 -_, ., '>:>-17. Cost of Purchases and Generation

,.,, .,. ·,,,. .. .., ' 30,006,681 - . ·--

18. Interchange - kWh - Net

19. Peak - Sum All kW Input (Metec-red) Non-coincident Coincident X 106,509

....

RlJS Fo1m 7


NM0004


December, 2009

INSTRUCTIONS See RUS Bulletin 1717B-2

PART I. INVESTMENTS

No DESCRIPTION 11Jr1 1mi::n i::vr, I INCOME LOSS RURAL DEVELOPMENT {a) l!i -· 1f- 1~l {e)

2 Investments in Associated Oraanizations COBANK CAPITAL CREDITS 423,127 1,000

FEDERATED RURAL ELECTRIC INSURANCE 82,002

NRECA MEMBERSHIP 10

PVT COOPERATIVE CAPITAL CREDITS 568 NRTC CAPITAL CREDITS 8,133

NRUCFC CAPITAL CREDITS 24,544 1,000

LEACO RURAL TELEPONE CAPTIAL CREDITS 8,852

NISC MEMBERSHIP 100

Totals 547.226 2,110

4 Other Investments ARTESIA COUNTRY MEMBERSHIP 525

Three Gold Krueaerands 1,163

Totals 1,688

6 Cash - General FUND-FIRST AMERICAN BANK SWEEP 8,065,339 100.000

I ACCOUNT

PCC FUND-FIRST AMERICAN BANK SWEEP 63,151

WORKING FUNDS 400

FLEXIBLE SPENDING NOW ACCOUNT 9,481

Totals 8,138,371 100,000

8 Temporarv Investments NEW MEXICO FORD MOTOR CREDIT 200,000

FORD MOTOR CO NOTES 100,000

1000 SHARES XCEL ENERGY STOCK 21,220

MERRILL LYNCH WCMA 754.879

FEDERAL HOME LOAN MORTGAGE 200,000

FIRSTBANK PUERTO RICO 98,000

MERRILL LYNCH B & T FSB 245,000

FIA CARD SERVICES. WILMINGTON DE 245,000 BANK OF AMERICA, NC 150,000

ACCRUED INTEREST 26,302 WESTERN ASSET INSTITUTIONA GOVT FUND 4,880,832

WETERN ASSET MONEY MARKET 2,168,369

FLAGSTAR BANK. FSB - Ml 96,000

BANK OF AMERICA, NA - NC 96,000

KEY BANK NATIONAL ASSOCIATION - OH 96,000

RBS CITIZENS, NA - RI 96,000

CHEVY CHASE BANK, FSB - VA 96,000

COLE TAYLOR BANK - IL 96,000

FIFTH THIRD BANK - OH 96,000

NEW SOUTH FEDERAL SAVINGS - AL 96,000

BANK OF NORTH GEORGIA - GA 96,000

CIT BANK- UT 96,000

SOVEREIGN BANK 96,000

BANK OF INDIA 200,000

GE CAPITAL FINANCIAL INC UT 200,000

MIDWEST BANK AND TRUST CO - IL 200,000

BARCLAYS BANK DELAWARE 200.000

INDEPENDENT BANK - Ml 96.000

GMAC BANK - UT 96.000

RUS Form 7

USDA-RU$ BORROWER DESIGNATION

NM0004


December, 2009

INSTRUCTIONS - See RUS Bulletin 17178-2

PART I. INVESTMENTS

FRONTIER BANK WA 96,000

FLUSHING SAVINGS BANK FSB - NY 50,000

SAEHAN BANK CA 96,000

BMW BANK OF NORTH AMERICA -UT 96,000

FIRST MIDWEST BANK - IL 96,000

CAROLINA FIRST BANK - SC i 96,000

AMERICAN EXPRESS BANK, FSB t 96,000

CAPMARK BANK - UT 96,000

DISCOVER BANK 96,000

SALLIE MAE BANK - UT 96,000

EDDY FEDERAL CREDIT UNION 26 253,725

FIRST FEDERAL BANK 253,129

ARTESIA CREDIT UNION 125,355

ARTESIA NATIONAL BANK 245,000

WESTERN COMMERCE BANK 250,000

ROSWELL COMMUNITY FEDERAL CREDIT UNION 246,828

FIRST NATIONAL BANK OF RUIDOSO 246,272

ARTESIA CREDIT UNION 125,108

Totals 8,151,628 5,645,417

9 Accounts and Notes Receivable - NET LINE EXTENSION CONTRACTS 249,022

RETIREE & EMPLOYEE ACCOUNTS RECEIVABLE 59,273

Totals 308,295

11 TOTAL INVESTMENTS (1 thru 10) 17,147,208 5,747,527

RUS Form 7


NM0004


December, 2009

INSTRUCTIONS See RUS Bulletin 17178-2

PART IL LOAN GUARANTEES

No ORGANIZATION DATE rt,Dlf"!III.. >\I LOAN DA ... ~~ RURAL DEVELOPMENT (a)

- .,

T~l lf (e)

Total

TOTAL (Included Loan Guarantees Only)

RUS Form 7

,JSDA-RUS BORROWER DESIGNATION

NM0004


December, 2009

INSTRUCTIONS - See RUS Bulletin 1717B-2

Part Ill. RA TIO

RA TIO OF INVESTMENTS AND LOAN GUARANTEES TO UTILITY PL/1NT 18.84 % [Total Of lr1cll1ded Investments (Partl, 11b) and Loan Guarantees Loan Be lance (Part I!, 5d) !o Tota! Ul!l1ty Plant (Form?. Part C Line3)]

PART IV. LOANS

No ORGANIZATION MATURITY DATE ORIGINAL AMOUNT LOAN BALANCE RURAL DEVELOPMENT (a) (b) ($) ($) (e)

(c) (dl

Total

RUS Form 7

Service Reliabi/i'ty

2009 Annual Report

edication

Toital Commitment to Our Members Since 1937

Facts Total Miles of Line:

3,687

Counties Served: Eddy Chaves Parts of Otero and Lea

Substations: 26

Number of Members: 3,735

Number of Meters: 12,638

Number of Employees: 65

Governing Body: Members are represented by a seven-member board of

trustees.

Date Incorporated: June 23, 1937

Power Supplier: Xcel Energy

Web Site: www.cvecoop.org

Vision:

To the Members of Central Valley Electric Cooperative, Inc.:

·'.'-l"otice is hereby given that the Annual Meeting of the memebers of Central Valley Electric Cooperative will be held Saturday, March 27, 2010, at the Artesia High School Auditorium (215 S. 15th Street) at

1 :30 p.m., for the following purpose:

1 .. To pass upon any reports covering the year 2009, including

acting upon reports of Trustees.

2,, To elect three members to the Board of Trustees. The Nominating Committee, appointed by the Board, presents the following candidates for

election to one 3-year term to the Board ofTrustees.

District 1 Artesia/Lakewood JACK CASE (Incumbent)

District 5 South of Roswell BILL THOMPSON (Incumbent)

District 2 Loco Hills JASON CIEMPA (Incumbent)

Any person voting for a company or a corporation at a membership meeting of the co-op must be an officer of that company or corporation, or be authorized, in writing, by an officer to vote. No person authorized in writing to represent a corporate membership will be allowed to register and vote for more than one membership. In the case of individual (non-corporate) membership, proxy voting is NOT allowed. Only the husband or wife may

register and vote the individual membership.

In witness whereof, this Notice has been issued by the Secretary/ Treasurer of Central Valley Electric Cooperative and its corporate seal

hereon impressed March 10, 2010.

Wesley R. Pilley Secretary /Treasurer

Central Valley Electric Cooperative is a member-focused electric cooperative dedicated to personalized service for its members and the economic vitality in the surrounding communities.

Charles T. Pinson, Jr. Executive Vice President

& General Manager

COOPERATION -SUPPORTIVE - UNITED -MUTUAL; are all synonyms for the word cooperative. Today, more than ever, we need our members support and their voices to be heard.

On numerous federal and state levels, legislation and regulations are be·ing considered which will affect the price our rne•mbers pay for their electricity. In Washington, D.C., and Santa Fe, cap-and trade legislation is being considered. At the same time the Environmental Protection

Agency (EPA) and the New Mexico Environmental Improvement Board wants to regulate greenhouse gas emissions such as carbon emitted from power plants. It is critical that any legislation or regulations imposed are achievable with today's technologies and recognize the impacts on our already struggling economy. Join us in the Our Energ),, Our Future (www.ourenergy.coop) campaign and stay tuned to the Beyond the Wire newsletter for ongoing information on these important issues and ways in which you can help, like contacting your state and federal lawmakers. By joining together we can have our voices heard and help form energy policies that will benefit us all.

As general manager of Central Valley Electric

Executive um ry the retirement of capital credits. In 2009, the board of trustees authorized the retirement of $1,205,037.82 in capital credits for the year 1990. If you were a member of the co-op in 1990 your capital credit check was mailed in March. If you have any questions about capital credits please call Glenda Gideon at (575) 746-3571.

In April 2009, CVE began collecting one percent of additional revenue from members which goes into the Renewable Energy and Energy Conservation fund. In nine months the co-op has collected $327,317 to be used for renewable energy and energy efficiency programs. By collecting this additional revenue, CVE saved about $163,659 (which also goes into the fund) in fees that would otherwise be paid to the state. The fund is to be used to help the co-op meet certain renewable portfolio standards set by state regulatory agencies, and to provide renewable energy and energy efficiency programs that will benefit members. For more information on current or upcoming programs please visit CVE's Web site at www. cvecoop.org.

The board of trustees continues to deliberate the future of the co-op's wholesale power supply. The current power contract with Southwestern Public Service Company (SPS) expires the end of 2015. The co-op has been actively working to negotiate a contract extension with SPS that will, over

time, decrease the amount of electricity they provide Cooperative, I am pleased to report, that thanks to the rate increase approved in 2009, your cooperative is financially strong and positioned well to meet your needs. The rate increase was the first in 23 years and was necessary in order to maintain strong equity levels and financial requirements of the USDA's Rural

CVE is financially strong & positioned well to meet your needs.

to the co-op. CVE is also pursuing membership in a generation and transmission cooperative (G& T) which will potentially replace SPS as our wholesale power provider. The G& T is structured much like CVE, with cost based rates and allocation of capital credits to member cooperatives that own the G& T.

Utilities Service.

The following summarizes the finances and operations of 2009:

• Sales in kilowatt-hours (kWh) DECREASED by approximately 33.5 million or down 4.5% from 2008.

• Operating Revenue was $45,911,865 down $10.5 million from 2008, which was a result of decreased wholesale power costs and lower fuel prices associated with power generation.

• 2009 Margins were $6,217,131, which is $4.3 million higher than 2008.

• 2009 Net Utility Plant was approximately $69 million.

• 2009 new Net Utility Plant added was approximately S4.8 million. CVE added two new substations in 2009. The West Artesia substation will provide added capacity to members west of Artesia. The Kewanee substation will help support the needs of oil and ga~; development in the oil field near Loco Hills.

One of the many added values associated with membership in CVE is

In July 2009, CVE underwent a major software conversion process. Because of this transition the co-~is better able to serve its members. One such change has been a new look to the bill format. The new bill provides members more detailed information on their electric usage. The new software also allows CVE to provide current technologies such as paying your bill online (E-Bill). We have experienced some difficulties with the conversion and appreciate our members being patient with us during this monumental transition period.

On behalf of the employees, board of trustees and management of your cooperative, I pledge to continue to fight to protect your interests. We ask that you join us in our efforts to work towards achievable energy policies in New Mexico and the United States. Together we will rise to meet the challenges of the future and continue to strengthen Central Valley Electric Cooperative and the communities it serves.

President

Darrell Atkins District 3

Cottonwood/Lake Arthur

District 4 Dexter /Hagerman

Trustee

Bill Thompson District 5

South ofRoswell

t s

Trustee

Jack Case District 1

Artesia/Lakewood

Vice President

Charles Wagner District 6

North of Roswell

Trustee

Jason Ciempa District 2 Loco Hills

Trustee

Michael Bennett District 7

Hope

;~

/'~

CVE Undergoes Majc»r Software Conversion

In 2009, Central Valley Electric Cooperative went through a major software conversion process. CVE

joined forces with the National Information Solutions Cooperative (NISC), an information technology company that develops and supports software and hardware solutions for utility co-ops across the country.

National Information Solutions CooperativEt

By converting to this new software system, CVE is better able to serve its members. The new billing and operating software has allowed the co-op to integrate various departments, better track information and reduce redundant entries in the accounting process.

As a result of the conversion, CVE has changed the look and format of the electric bills that are sent to members. The new bill format provides member's with more detailed information on their billing and electricity

usage. The new software also allows CVE to offer members current technologies such as paying your bill online (E-Bill).

During the transition we did experience some minor bumps in the road, and CVE appreciates your patience

and cooperation. However, we ask that you bear with

us as we continue to go forward with this much needed upgrade to your cooperative.

Like CVE, NISC is owned by the users of their

Changes at

systems. Today NISC, serves more than 500 energy and telecommunications cooperatives in 47 states. NISC's technologies, knowledge and people have helped rural electric cooperatives better conduct business and serve their members for over 40 years.

Together with NISC, Central Valley Electric Cooperative will continue to provide the kind of outstanding service you have come to rely on as well as offer new services and features.

Total Utility Plant in Service

Construction Work in Progress

Less Accumulated Depreciation

* Net Utility Plant in Service

Invest. in Assoc. Org.-Patronage Capital

Invest. in Assoc. Org.-Nongeneral Funds

Other Investments

*Total Investments

ary Investments

·-~ vable t,

·. able-Sale of Energy ·~~f:.:·,--·c::eivable-Other ·;·,-t'I' '\ ..l~

Materials and Supplies-Electric & Other

Balance Sheet December 31, 2009

IS 86,455,339 Patronage Capital

4,514,532

~ :$ 69,023,651

549,336

0

1 688

Operating Margins Prior Years

Operating Margins Current Year

Non-Operating Margins

Other Margins & Equities

* Total Margins & Equities

Long Term Debt - RUS

(Payments Unapplied $ 4,591,085)

$ 551,024 Long Term Debt Other

* Total Long Term Debt

8,2 t · Obligations Under Capital Leases

13,797,045 Accumulated Operating Provisions

249,022

$ 37,304,381

288,272

5,730,308

686,209

~ $ 43,892,403

28,091,107

~ $ 42,633,443

0

403 691

2,688,998 *Total Other Non-current Liabilities$ 403,691

59,273

2,255,122

84,256

6477 <ilther Current and Accrued Assets

*Total slrent and Accrued Assets $ 27,378,564

Accounts Payable

Consumers Df posits

Other ct/rfj& Ac:1LeJ~iabili~ies

* Total lurrent & Accrijed Lia llties

3,168,755

100,567

~ $ 5,924,834 I

f 0

-72l079 $ 2§~1®1~;:t:i·;

1,1 ! ·: ',,

' . • ; .f

Electric and Other Revenue

Purchased Power Operations & Maintenance Depreciation Taxes Interest _ - --· Extraordinary It~~s-'Other Deductions

Financial I for

Income Statement

$ 47,818,420 $ 56,501,997

$ 37,302,098 $ 45,363,273

5,572,038 5,683,586

2,288,647 2,466,997

362 369 ' ~ I ,,

1,522,449 1,556,796

$ 45,911,865

$ 29,951,429

6,109,973 2,614,023

373

Cooperation Among r tiv s COOPERATION AMONG COOPERATIIVES is one of

the seven principles that makes being a member of an electric co-op unique, and that is why helping our

neighbor cooperative (Otero County Electric Coopera

tive) was just the right thing to do.

On December 8, 2009, in the face of a frigid north

west wind, Central Valley Electric Cooperative and

Deans, Inc. sent crews to help restore power to the residents of Cloudcroft, Weed, Mayhill, Pir,on, Sacra

mento and those who lived between in the remote,

isolated mountains. Winds had peaked at 80 to 90 mph toppling trees and knocking down power lines leaving the area without any electricity.

As the CVE and Deans teams left, other teams of

linemen were already in route from Texas, Oklahoma, Arizona and New Mexico. In total 150 linemen an

swered the call for help said Clint Gardner, Manager of

Member Services at Otero County Electric Cooperative.

"They were a great bunch of guys and our hats go off to them because we couldn't have done it alone;' said

Gardner. It was truly an amazing feat in the face of such

harsh conditions. "Mobility was severely impaired as

there was two feet of snow on the ground;' Gardner

said.

After working tirelessly for three days, the crews returned home on December 11, 2009, having restored power to everyone in their assigned sector.

Marie Birch Retires After 24 years of service Marie Birch has retired

from Central Valley Electric Cooperative. Birch joined the CVE team in 1984 and worked as an insurance clerk and receptionist.

"CVE is a wonderful place to work, and I think it's because of the people;' Birch said of her years with the co-op.

The board of trustees, management and employees of CVE would like to thank Marie for her many years of dedicated service to the cooperative and its members.

In Memory L. C. "Red" Mayberry 1922 to 2009

• Employee r1

Red Mayberry worked for Central Valley Electric Cooperative for over 30 years before he retired in 1984 as a Foreman. Red worked hard for over three decades to help build CVE into the co-op it is today.

Mr. Mayberry is survived by his wife Delores; step-son Mark Felton; step-daughter Mary Emily Curry; four grandchildren; and 10 great-grandchildren.

From Left to Right: Tom Hit, Robert E. Lee, Joe Gray, Mattie Newsome, Mike Goss, Mac McGee, Johnny Balencia, Red Mayberry, Curtis Harrison.

Central Valley Electric Cooperative, Inc. PO Box 230 Artesia, NM 88211-0230 (575) 746-3571 • www.cvecoop.org

- •• Ii•• Central alley Electric You are invited to the cooperative's

, LUNCH• 11:30 AM to 12:45 PM Park Junior High Cafeteria .. 1508 \/1,/. Cannon • Artesia

REGISTRATION • 12:30 PM TO 1 :30 PM Artesia High School Auditorium• 215 S. 15th .. Artesia

MEETING• 1:30 PM AHS Auditorium

em ers

PRESORTED STANDARD U. S. POSTAGE

PAID ARTESIA. NM

PERMIT No. 204

*Prize list not all inclusive and subject to change. To be eligible to win, you must be registered, be an active member of CVE receiving service at least 14 days prior to the meeting, meet all rules stipulated in the Notice of Annual Meeting (page 2)

and attend the business meeting.

· new mexico public regulation commission att: mr. ronald x. montoya 1120 paseo de peralta santa...

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