REVISION DATE: 12-22-13 REASON FOR REVISION: Updated Wellbore Schematic to new form.

Lower Casing Extension w/ Mule shoe 7.368'' 5.924'' 16.81' 4843.19' 4860.00'

7.395'' 5.907'' 3.66' 4829.13' 4832.79'Baker SLP-R Packer w/6' Tie-Back Receptacle 7.555'' 5.829'' 10.40' 4832.79' 4843.19'

Seal Assembly with 5 sets of Molyglass seals (7.31' overall, stabbed in 3.65')

Baker SLP-R Packer Assy. includes 2' Tie-Back Extension and X-Over 7.550'' 5.834'' 8.88' 4739.41' 4748.29'2 joints 6-5/8", 24#, Buttress Casing 7.390'' 5.921'' 80.84' 4748.29' 4829.13'

5808' (5221' T.V.D.)

5806' (5219' T.V.D.)

3.02'6.050'' 4.892''

5-1/2", 17#, .016 ga. Bakerweld screen

Baker Shear Out Safety Joint (54K)

Original Drilled Depth

5806.00'

5-1/2", 17#, .016 ga. Bakerweld screen 5.500'' 4.892'' 5800.99'

8-5/8" PRODUCTION CASING DETAIL

Baker GPV Set Shoe

29.96'

3.540''5.500''36.48'

6.050'' - 1.90'

5764.51'

5-1/2", 17#, .016 ga. Slimpack screen

3.11'

5764.51'

5804.10'

5-1/2", 17#, L-80, LTC Blank Pipe 5.500'' 4.892''

Bottom of 8-5/8" Production Casing:

5800.99'

6-5/8", 24# Upper Extension 5634.57'

37.97'5643.21'5642.45'

5701.14' 5704.16'

5744.33'

5704.16'5734.12'10.21'5.970'' 4.892''

4.892''5.970'' 20.18'

5744' (5165' T.V.D.)

5-1/2", 17#, L-80, LTC Blank Pipe 5663.17' 5701.14'6-5/8" X 5-1/2" LTC Lower Extension

7.000'' 4.750'' 1.84'Baker 80-47 Seal Bore

5.500'' 4.892''4.892''

.76'6.625'' 4.750''19.96'6.625''

5643.21'

6 joints 2-3/8", 4.7#, 8rd, EUE Tubing w/TDC

3-1/2" EUE Box X 2-3/8" EUE Pin X-Over

286.05'

.45'5306.04'

2-3/8" TDC cut at 45º MuleShoe

6-5/8" SCAB LINER DETAIL O.D. I.D. Length Top

284.07'286.05' 4739'

287.69'1.64'3.82'3.91'

Baker Profile Nipple "B" (2.812)

.40'

9.92'

287.69'291.51'295.42'305.34'

291.51'295.42'

178 joints 2-3/8", 4.7#, 8rd, EUE Tubing179.96'

Baker Model T-5 Dhsv SN-502436Flow Coupling w/3-1/2" Box X Box X-Over8-5/8" Baker Model RC-2 POTH SN-564275

284.07'

6-5/8", Scab Liner Top Baker "SLP-R" Packer

5611.83'

16.93'.96'

252.05'10.00'4.13'1.98'

1 pup joint 3-1/2", 9.3#, 8rd, EUE TubingBaker Control Head

279.94'

280'

580'

20" Conductor Pipe, Cemented

81'

Rucker-Shaffer

K.B. to Tubing HangerTubing Hanger8 joints 3-1/2", 9.3#, 8rd, EUE Tubing1 pup joint 3-1/2", 9.3#, 8rd, EUE Tubing

Length Bottom-

16.93'17.89'

269.94'

-17.89'

269.94'279.94'

Top of Baker T-5, RC-2 Hanger, Downhole Safety

Valve Assembly

13-3/8", 61#, K-55, Surface Casing

Estimated Top of Cement Surface

Top2-3/8" TUBING DETAIL

(4) 1/2" WSO Holes

5792'Bottom of 2-3/8", 4.7#

Tubing String

5734.12'

Bottom of 5-1/2" Production Liner

5804.10'

5744.00'

5663.17'

Hole Underreamed To

Hole Opened To5808'

14"

8-5/8", 36#, K-55 Production Casing

Estimated Top of Cement Surface

146 joints of 8-5/8", 36#, K-55, Armco Seal-Lock Casing. Baker Model "J" Stage Collar at 4792'. Baker Flexiflow Fillup Collar at 5701'. Baker Cement Guide Shoe at 5744'. Cemented in two stages with 2196 sacks of a combination Class "G" and "Pozmix" cement.

5640.61'Baker 80-47 Sliding Sleeve 5640.61'

5744.33'

5-1/2" O-Ring Seal Sub

5642.45'

5-1/2" PRODUCTION LINER DETAILBaker SC-1 (86AB-47) Packer 5629.86'

5791.79'

5680'

Top of 5-1/2", 17# Production Liner with Baker

"SC-1" Packer

4792'Baker Model "J" Stage

Collar

4860'

6-5/8", Scab Liner Bottom Baker "SLP-R" Packer

5630'

5791.79'

305.79'5611.83'

5792.19'

305.34'305.79'

Bottom

Bottom

6.04'5634.57'

LengthO.D. I.D.4.71'7.625'' 4.750''

Top

6.625'' 5.921''

WELLBORE SCHEMATIC TURNER CUT-6S

Pacific Gas & Electric Company McDonald Island Gas Field A.P.I. number: 077-20205

Original K.B. to Tubing Hanger: 16.93' Top of Ground: -10.00'

Spud Date: 7-31-1973 Last Recompletion Date: 10-26-2010

API# ______________________ WELL ID: __________________________________

RECORDS RECEIVED Date Rec'd

Records Ok- 2 copies of

each

Needsadditionalrecords

Copies in box for

IHS121 entry

RemarksWell Summary (OG100)History (OG103)Directional SurveyE-logs (2")E-logs (5")MUD LogsCBLOther

ABANDONMENT

NEEDS S f I ti

DISTRICT 6 - WELL RECORDS CHECKLIST

RELEASE DATE

CONFIDENTIAL

NOTICE FOR: drill rd rw abd

P-number(s) __________________ & __________________

DATE

Date Completed

Remarks _____________________________________

__________________________________________________________________________________________ BOND RELEASE __________

DATE

Database entry by:______

MAP#______ BY: ______________ DATE:

Idle-gasAbandoned-gasDrilling-Idle

Final Letter Completed by: _____ Date

Surface Inspection COMPLETED by ______

NEEDS Surface Inspection

MAP MADE for Surface Inspection Box STATUS

Producing-gas

Water DisposalObservationAbandoned-dry hole

Other

RECORDS APPROVED

FINAL LETTER NEEDED

077-20205 "Turner Cut" 6-S

610-192

Nov 29, 2010 JC 2/16/11

N/C

JAS

Print Form

Feb 16, 2011

SUBMIT IN DUPLICATERESOURCES AGENCY OF CALIFORNIA

DEPARTMENT OF CONSERVATIONDIVISION OF OIL AND GAS

History of Oil or Gas Well

Operator: Pacific Gas and Electric Company Field: McDonald Island

Well Number: Turner Cut 6S API#: 077-20205 Sec. 30, T. 2N, R. 5E, MDB&M

Signature: ~ aA.d A (}L.:..e..Donald A. Oliveira

Date: November 20, 2010

Address: 375 North Wiget Lane, Suite 130, Room 101, Walnut Creek, CA 94598

10/15/10: Commenced operations at 10:00 hrs. Completed connecting kill manifold lines. Held safetymeeting with all hands on location. Opened DHSV and prepared to kill well. Pumped 74 pcfl42vis polymer fluid down tubing and vented casing gas at 90 strokes per min. Fluid to surface at5800 strokes. Vac trucks transferring 120 bbls of extra brine into the pits to build volume. Welltook approximately 130 bbls. Circulated fluid to build vis and weight. Shut in and checked forflow, no flow. Well dead. Installed back pressure plug and nippled down tree.

10/16/10: Installed BOPE and kill lines. Tested blind rams and pipe rams to 1500 psig, test good. TestedHydril bag to 1000 psig, test good. Reinstalled rig floor. Removed back pressure plug. Backedout studs on tubing hanger. Unset the DHSV. Pulled out of hole with the DHSV and laid itdown. Circulated hole clean. Quality rigged up lay-down machine. Pulled out of hole and laiddown tubing string. Changed pipe rams to 3-112" and function tested to 1500 psig. Called D.O.G.but they declined to witness the BOPE test. Picked up six 4-3/4" drill collars and 3-112" drill pipeand ran in hole. Started circulation.

10/17/10: Continued to circulate fluid. Pulled out of hole with drill pipe. Rigged up Baker Atlas forchemical cut. Made chemical cut at 5720'. Baker Atlas rigged down. Ran in the hole withBaker model "C" bridge plug and set at 300'. Tested to 2000 psig, test good. Installed new casingwing valves and tested to 2000 psig, test good. Pulled out of hole with the bridge plug and laid itdown. Picked up and ran in hole with fishing tools to retrieve the top Baker SLP-R scab linerpacker. Set spear and pulled up. Unset SLP-R and circulated two bottoms up. Checked for flowand well flowing back. Restarted circulation and worked pipe up and down. Checked flow everyhour. Well continued to flow back.

10/18/10: Continued to circulate and work pipe. Checked flow every hour. Flow stopped. Pulled out ofhole with packer and two joints of 6-5/8" scab liner and laid down. Picked up tools to retrieve thebottom Baker SLP-R scab liner packer and ran in hole. Sheared packer loose 120K. Checked forflow, no flow. Retrieved bottom scab liner packer. Pulled out of hole and laid down packer andretrieving tools. Picked up 8-5/8" casing scraper and ran in hole. Tagged bottom at 5646'.Circulated two bottoms up and checked for flow, no flow. Pulled out of hole and laid downscraper. Made up Baker retrieving tools for the SC-1 liner packer and ran in hole to top ofliner at5649'. Circulated and pulled liner hanger free with 140K.

1

SUBMIT IN DUPLICATERESOURCES AGENCY OF CALIFORNIA

DEPARTMENT OF CONSERVATIONDIVISION OF OIL AND GAS

10119110: Circulated two bottoms up and checked for fill. Pulled out of hole with the SC-l liner packer.Recovered 86' of the liner cut section from the hole. Laid down cut section and retrieving tools.Made up and ran in hole with the washover assembly. Tagged top offish at 5739'. Washed overliner and tagged bottom at 5811 ' . Circulated two bottoms up. Pulled out of hole with washoverassembly and laid it down. Made up overshot assembly and ran in hole to recover liner.

10/20/10: Continued to run in hole with overshot to recover liner. Latched onto liner. Set the overshot andpulled the liner. Pulled out of hole with the overshot and liner and laid down. Made up and ranin hole with the 7-5/8" O.D. bladed flat bottom mill assembly. Tagged bottom at 5797', 11' offill. Cleaned out hole to 5808' and circulated two bottoms up. Pulled up into the shoe and closedthe bags. Transferred dirty polymer to storage. Cleaned rig pits. Filled rig pits with filtered 74pcf polymer. Ran in and tagged for fill, no fill. Pulled up 2' and changed over hole. Circulatedto condition new fluid and checked for flow, no flow. Pulled out of hole with mill assembly andlaid it down. Picked up 14" hole opener and started to run in hole.

10/21110: Continued to run in hole with the hole opener. Attempted to open hole but tool appeared to beplugged. Circulated for half an hour and tool operated normally. Found shoe at 5744'. Openedhole from 5744' to 5808'. Circulated. Shut in circulation and checked for fill, no fill. Pulled outof hole with hole opener and laid down tools. HELD BLOWOUT DRILL. Ran in hole with the2-7/8" drill pipe test sub. Dropped test ball. Pulled up into the shoe and waited for ball to fall.Pressured drill pipe to 2000 psig for 5 mins., test good. Sheared test screws at 2400 psig andstarted circulating. Shut in circulation. Transferred hole opening fluid to storage and cleaned therig pits. Filled rig pits with clean filtered 74 pcf brine for gravel packing and started to changeover the fluid in the hole.

10/22/10: Completed change over and pulled out of hole with the test sub. Held safety meeting for runningthe liner. Measured and picked up the new production liner and ran in hole. Tagged bottom at5800', 8' high. Rigged up kelly and circulated out fill. Shut in circulation. Tagged bottom at5807'. Held safety meeting for setting SC-l packer. Set new SC-l packer with 1300 psig, 1800psig, 2200 psig. Anchor tested, test good. Tested backside to 1200 psig, test good. Blew ballseat at 3800 psig. Bottom of liner at 5806'. Top of liner at 5630'. Rigged up and tested gravelpacking tools. Gravel packed well. Pumped 94 cu/ft of gravel. Reversed out 25 cu/ft. 69 cu/ft inplace. Re-stressed pack to 1500 psig at .7 bpm. 50 second bleed off. Pulled out of hole with thegravel pack tools and laid down. Picked up 2-3/8" stinger and ran in hole. Reversed circulatedhole and rigged up Delta for the hot water treatment.

10/23/10: Continued to rig up the Delta hot water truck. The hot water truck circulated brine and broughtthe fluid up to temperature. Circulated brine to bond the resin coated gravel. Completed 16 hourcirculation. Shut in burners on the hot water truck. Circulated to cool down. Rigged down Deltahot water truck and pulled out of hole with the stinger and laid it down. Made up and started torun in hole with the bottom Baker SLP-R packer for the scab liner.

2

SUBMIT IN DUPLICATERESOURCES AGENCY OF CALIFORNIA

DEPARTMENT OF CONSERVATIONDIVISION OF OIL AND GAS

10/24110: Continued to run in hole with the bottom SLP-R packer for the scab liner. Rigged up the Bakerpump truck. Held safety meeting with all hands for setting packer. Set bottom SLP-R at 4860'.Pulled out of hole with Baker's setting tools. Picked up scab liner and top SLP-R packer and ranin hole. Stabbed the tie-back extension into the bottom SLP-R packer. Tested the backside at500 psig, test good. Set the top packer with 2900 psig. Anchor tested, test good. Pressured up to3088 psig and blew the seat. The top SLP-R packer set at 4739'. Rigged down the Baker pumptruck. Quality rigged up lay down machine. Pulled out of hole with drill pipe and SLP-R settingtools and laid down. Changed pipe rams to 2-3/8" and function tested. Rigged up Quality pick upmachine. Started to run in hole with 2-3/8" tubing.

10/25110: Continued to run in hole with the tubing string. Picked up and ran in hole with the DHSVassembly. Tested the control line to 3200 psig for 15 mins., test good. Landed the tubing hangerand tightened the lock down pins. Set the packer pressure in stages at 4800, 5200, 5800, 6200psig. Pressured to 7500 psig for 30 mins, test good. Pressured backside to 400 psig for 5 mins,test good. Bled pressures and closed valves. Nippled down the BOPE. Installed the tree. Treetested to 3000 psig. Tree did not hold pressure. Tightened connections on tree and retested at3000 psig, 15 mins, test good. Tested the hydraulic connections at 4000 psig for 15 mins, testgood. Removed the back pressure valve. Rigged up bring in separator and lines. Pressure testedlines for leaks, test good. Waited for daylight to bring in well.

10/26/10: Daylight arrived. Held safety meeting for bringing in the well. Unloaded well. Flared both tubingand casing. Stopped flaring. Recovered approximately 367 bbls of fluid. Shut in for 30 mins.Recovery pressures: Tubing/1800 psig and Casing/2010 psig. Pressured hydraulic line for DHSVto 7500 psi and hold for 30 mins., test good. Leak checked DHSV. Casing leak rate at 1.83 cufftin 10 min. Tubing leak rate at 1.37 cufft in 10 min. Secured well. Released rig at 1700 hrs.

5-1/2" Liner DetailDESCRIPTION DEPTH LENGTH 0.0. 1.0.

.FT .FT INCH INCH1 Baker Model SC-1 Packer Size 86AB-47 5629.86 4.71 7.625 4.7502 Upper GP Extension 5634.57 6.04 6.625 5.9213 84-47 GP Sliding Sleeve 5640.61 1.84 7.000 4.7504 84-47 GP Seal bore 5642.45 0.76 6.625 4.7505 Lower GP Extension 6-5/8" X 5-1/2" LTC Pin 5643.21 19.96 6.625 4.8926 Blank Pipe 5-1/2", 17#, L-80 LTC 5663.17 37.97 5.500 4.8927 Shear-Out Safety Joint Pin to shear at 54k 5701.14 3.02 6.050 4.8928 Blank Pipe 5-1/2",17#, L-80 LTC 5704.16 29.96 5.500 4.8929 Slim Pack Screen 5-1/2" X .016 Ga. 5734.12 10.21 5.970 4.89210 Bakerweld Screen 5-1/2" X .016 Ga. 5744.33 20.18 5.970 4.89211 Bakerweld Screen 5-1/2" X .016 Ga. 5764.51 36.48 5.500 4.89212 O-Rinq seal sub 5-1/2" LTC Box X Pin 5800.99 3.11 5.500 3.54013 GPV Shoe 5804.10 1.9 6.050 0.000

Bottom Of Liner 5806.00

3

SUBMIT IN DUPLICATERESOURCES AGENCY OF CALIFORNIA

DEPARTMENT OF CONSERVATIONDIVISION OF OIL AND GAS

6-5/8" Scab Liner DetailDESCRIPTION DEPTH LENGTH 0.0. 1.0.

.FT .FT INCH INCH1 Baker Model SLP-R Hanner Packer 6-5/8" X 8-5/8", 24#, 8Rd 4739.41 6.40 7.550 5.8342 Crossover LTC Box X 6-5/8" Buttress 4745.81 2.48 7.340 5.9543 1 joint 6-5/8",24#, Buttress Casing, K-55 4748.29 41.22 6.625 5.9214 1 joint 6-5/8", 24#, Buttress Casino, K-55 4789.51 39.62 6.625 5.9215 Crossover Buttress Box XL TC Pin 4829.13 1.81 7.395 5.9396 6.750" Baker Molyglass Seal Assembly 4830.94 1.85 7.276 5.9077 Tie Back Extension SLP-R Hanner Packer 6-5/8", 24# X 8-5/8" 4832.79 10.40 7.555 5.8298 6-5/8", 24# Lower Casing Extension 4843.19 16.08 7.368 5.9249 6-5/8" Mule Shoe 4859.27 .73 7.301 6.757

Bottom of Scab Liner 4860.00

Tubing DetailDESCRIPTION DEPTH LENGTH 0.0. 1.0.

.FT .FT INCH INCH1 Kelly Bushing to Tubing hanger 16.932 Tubinq Hanner 16.93 .96 2.9923 8-Joints 3-1/2" J-55 9.3# EUE 8Rd Tubing 17.89 252.05 4.570 2.9924 1-10' Pup Joints 3-1/2",9.3#, J-55, EUE 8Rd Tubing 269.94 10.00 4.570 2.9925 1-4' PuP Joint 3-1/2",9.3#, L-80 EUE 8Rd Tubing 279.94 4.13 4.570 2.9926 Baker Control Head w/4300 psi Relief Valve 3-1/2" 8Rd 284.07 1.98 4.160 2.9927 3-1/2" (UB"Profile 2.812) 286.05 1.64 4.510 2.8128 Baker DHSV T-5 (SN 502436) 287.69 3.82 5.370 2.8129 Flow Coupling 3-1/2" 9.3# EUE 8Rd 291.51 3.12 4.510 2.99210 X-Over 3-1/2" 9.3# Box X Box 294.63 0.79 4.480 2.99211 Baker DHSV 32-40# RC-2, w/ 36,000 Shear (SN 564275) 295.42 9.92 7.540 2.99212 3-1/2" Box X 2-3/8" Pin X-Over 305.34 .45 3.540 1.99513 178-Joints 2-3/8" 4.7# Tubing 305.79 5306.04 2.910 1.99514 6-Joints 2-3/8 4.7# Tubing wlTurned Down collars 5611.83 179.96 2.910 1.99515 2-3/8" Mule shoe cut at 45° 5791.79 .40 2.910 1.995

Total Tubing Length 5792.19

4

NATURAL RESOURCES AGENCY OF CALIFORNIA

DEPARTMENT OF CONSERVATION DIVISION OF OIL, GAS AND GEOTHERMAL RESOURCES

PERMIT TO CONDUCT WELL OPERATIONS

Blanket Bond cc: Update

pc/syh Engineer: Pam Ceccarelli Elena M. Miller, State Oil and Gas Supervisor

Phone: (916) 322-1110 By Original Signed by Hal Bopp, Deputy Supervisor

A copy of this permit and the proposal must be posted at the well site prior to commencing operations. Records for work done under this permit are due within 60 days after the work is completed or the operations have been suspended. Issuance of this permit does not preclude the recipient from the obligation of being in compliance with all applicable Federal, State and Local laws, regulations and ordinances.

OG 111

Linda Y.H. Cheng, Agent Sacramento, California

Pacific Gas & Electric Co. April 1, 2010

77 Beale Street, B32

P.O. Box 770000

San Francisco, CA 94177

Your proposal to Rework well “Turner Cut” 6-S, A.P.I. No. 07720205, Section 30, T. 2N, R 5E, MD B. & M., McDonald Island Gas Field, Area, No Pool Breakdown Pool, San Joaquin County, dated 3/30/2010, received 4/1/2010 has been examined in conjunction with records filed in this office. THE PROPOSAL IS APPROVED: 1. Blowout prevention equipment, as defined by this Division’s pub lication No. M07, shall be installed and

maintained in operating condition and meet the following minimum requirements: a. Class II 3M on the 8 5/8” casing. b. A 3M lubricator for wire line operations.

2. The Division is furnished copies of any draw down or back pressure tests performed. In addition, the Division

will monitor the production for a period of six months and if anomalous water production is indicated, remedial action will be ordered.

3. The Division is promptly notified of any blowouts, fires, serious accidents, or any significant gas or water leaks.

4. No program changes are made without prior Division approval.

No. P 610-192

452 452 (Old) Field Code (New)

00 00 (Old) Area Code (New)

00 00 (Old) Pool Code (New)

RESOURCES AGENCY OF CALIFORNIADEPARTMENT OF CONSERVATION

DIVISION OF OIL, GAS, AND GEOTHERMAL RESOURCES

NOTICE OF INTENTION TO REWORK I REDRILL WELL

C.E.Q.A. INFORMATION (when redrilling or deepening only)

Exempt 0 Neg. Dec. 0 E.I.R. 0 Documentnot

requiredby local

Class S.C.H. No. S.C.H. No. jurisdiction 0See Reverse Side

FOR DIVISION USE ONLY

Forms EDPWell

Bond OGD114 OGD121 File

This notice and an indemnity or cash bond must be filed, and approval given, before the reworklredrill begins. (See the reverse side for bondinginformation.) If operations have not commenced within one year of receipt of the notice, this notice will be considered canceled.

In compliance with Section 3203, Division 3, Public Resources Code, notice is hereby given that it is our intention to

reworklredrill well Turner Cut 6S API No . ..:::0..:..7-'-'72:::;0::.:2".,0:..::5=--_(Circle one) (Well designation)

Sec. 30 T. 2N R. 5E _----'.!M!'-'.D=.,B.&M. McDonald IslandField

San Joaquin County.

1. The complete casing record of the well (present hole), including plugs and perforations, is as follows:1. 5-1/2" 0.0.17# K-55 with Baker Screen from 5649' to 5806' M.D.2. 8-5/8" 36# K-55 smls from surface to 5744' M.D.3. 13-3/8" 0.0. 61# smls from surface to 580' M.D ..

2. The total depth is:,..,5",,8-,,-08,,-'--,'(""5=22=-1'--'TV'--'--'D:...<) _ feet. The effective depth is: ...,5:..::8:..::0",8_' _ feet.

3. Present completion zone (s):..:..:M:..::c:::D::.:o::.:n.:,:a:..::ld"-- _ Anticipated completion zone (s):_M_c'-D_o"-n....:a_ld=-- _(Name) (Name)

4. Present zone pressure:...c1c.:7...:O:..::O'-- _ psi. Anticipated/existing new zone pressure:_1;..c8:...;5:...;0'-- _ psi.

5.Lastproduced:~T~h~is~is~a~ ~g~a~s~st~owra~g~e~w~e~II~------- _(Date) (Oil, BID) (Water, BID) (Gas, MctlD)

(or)Last injected: _

(Date) (Water, BIO) (Gas, MctlO) (Surface pressure, psig)

6. Is this a critical well according to the definition on the reverse side of this form? Yes 0 No ~

The proposed work is as follows: (A complete program is preferred and may be attached.)Please see attached program for details.

1. Remove and replace the Down Hole Safety Valve.2. Remove and replace scab liner over stage collar@ 4792'.3. Remove old liner and replace, gravel pack well.

For redrilling or deepening: _(Proposed bottom-hole coordinates) (Estimated true vertical depth)

The division must be notified if changes to this plan become necessary.

Address

375 N. Wiget Lane, Suite 250 ICity

Walnut CreekZip Code

94598

Name of Operator

Pacific Gas & ElectricTelephone Number

(925) 974-4111

Name of Person Filing Notice

Robert QuijalvoSignature

Robert QuijalvoDate

3/30/10

File In DuplicateOG107 (7/97/GSRl5M)