The URL can be used to link to this page

Home My WebLink About209-010 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov November 21, 2023 Mr. Noel Nocas Kenai – Area Operations Manager Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Re: Location Clearance Stump Lake 41-33RD (PTD 2090100) Dear Mr. Nocas: On November 16, 2023, the Alaska Oil and Gas Conservation Commission (AOGCC) received your email request for final location clearance of the Stump Lake 41-33RD. Surface abandonment was witnessed by an AOGCC Inspector on March 11, 2018. The post-abandonment location inspection was conducted by AOGCC on July 15, 2023. A copy of the location inspection report was provided to Hilcorp Alaska LLC on November 20, 2023. Based on AOGCC inspections, the Stump Lake 41-33RD drill site is compliant with onshore location clearance requirements as stated in 20 AAC 25.170. The AOGCC requires no further work on the subject well or location at this time. However, Hilcorp Alaska LLC. remains liable if any problems were to occur with this well in the future. Sincerely, Brett W. Huber, Sr. Chair cc: Ashley Ethridge, DNR (ashley.ethridge@alaska.gov) Chad Helgeson, Hilcorp (chelgeson@hilcorp.com) Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.21 12:44:43 -09'00' 2023-0715_Location_Stump_Lake_41-33RD_am Page 1 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 7/15/2023 P. I. Supervisor FROM: Austin McLeod SUBJECT: Location Inspection Petroleum Inspector Stump Lake Unit 41-33RD PTD 2090100 Hilcorp Alaska LLC 7/15/2023: Traveling to Beluga I met up with Brian Wooley to witness the location clearance of the above buried well. Location was free of trash with no visible evidence of where the well had been cut off and buried. Brian knew the general area on the pad where the well was, but it was difficult to see. It had been raining for the past few days so quite a bit of standing water was present on the pad. No sheens observed. At the entrance of the pad there are two delineators, one in each corner. I found no issues with this inspection. Attachments: Photos (6)     2023-0715_Location_Stump_Lake_41-33RD_am Page 2 of 4 Location Inspection – Stump Lake 41-33RD (PTD 2090100) Photos by AOGCC Inspector A. McLeod 7/15/2023 2023-0715_Location_Stump_Lake_41-33RD_am Page 3 of 4 2023-0715_Location_Stump_Lake_41-33RD_am Page 4 of 4 From:Regg, James B (CED) To:AOGCC Records (CED sponsored) Subject:FW: Stump Lake well 41-33RD location clearance Date:Wednesday, September 22, 2021 9:40:47 AM Stump Lake 41-33RD (PTD 2090100) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (CED) Sent: Wednesday, September 22, 2021 9:35 AM To: Henspeter, Mark A (DNR) <mark.henspeter@alaska.gov> Subject: RE: Stump Lake well 41-33RD location clearance Hilcorp has not requested our inspection. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Henspeter, Mark A (DNR) <mark.henspeter@alaska.gov> Sent: Wednesday, September 22, 2021 9:30 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Subject: Stump Lake well 41-33RD location clearance Hi Jim, Just had a quick question for you about an onshore location clearance for Hilcorp’s Stump Lake 41- 33RD well on the Stump Lake pad in Cook Inlet (permit 209010). I believe there was some diesel contamination they discovered during the P&A, but that was resolved last year, and the rest of the facilities on the pad have since been removed. We have been working to close out the Plan of Operations for the site, and the final location clearance will be a necessary part of that. Has Hilcorp requested anything for location clearance yet? DOG is planning to visit the area soon (before snowfall) and will plan to perform a site inspection and collect aerial imagery as we have done with other sites. We would be happy to collect and provide imagery and information to AOGCC to support a location clearance, or could possibly coordinate with an AOGCC inspection if you plan to send an inspector this fall. Thanks! -Mark Henspeter Natural Resource Specialist Division of Oil & Gas Permitting Section Phone: 907.269.8812 mark.henspeter@alaska.gov THE STATE o'ALASKA GUV'I[RNOR.NIIKE DUNLF.AVY May 15, 2020 Kelley Nixon Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Department of Environmental Conservation DIVISION OF SPILL PREVENTION AND RESPONSE Prevention, Preparedness, and Response Program 555 Cordova Sheet Anchorage, AK 99501-2617 Main: 907-269-7557 Fax: 907-269-7687 w .dec.alaska.gov Subject: Hilcorp Stump Lake Pad Historic Contamination, Spill #:18239906901, No Further Action Dear Ms. Nixon: The Alaska Department of Environmental Conservation (department) has completed its review of the case file for the above referenced spill, including the Stump Lake Well SLU 41-33RD P&A Excavation Sampling Report prepared by Jacobs Technology Inc. dated December 2019. This report gives a summary of the cleanup actions that were taken, including excavation and disposal of petroleum impacted soil and confirmation sampling within the excavation footprint indicating that the department's method 2 MTGW cleanup levels have been met at the excavation limits. Based on the information in the aforementioned report, the department has determined that the site does not pose a threat to human health, safety, or welfare or to the environment and no further containment or cleanup is required for this site at this time. If additional areas or levels of contamination are discovered in the future that are not included in the information submitted to the department, you are required under 18 AAC 75 to contact this office at 907-269-3063. In addition, cost recovery under Alaska Statute 46.08.070 will continue until all state costs have been reimbursed. If you have questions or comments regarding this matter, please contact me at 907-269-7557 or mike.evans@alaska.gov. Sincerely, Mike Evans Environmental Program Specialist Ms. Kelley Nixon 2 May 15, 2020 Hilcorp Alaska, LLC cc: Lisa Krebs-Barsis, ADEC Crystal Smith, ADEC Stu Greenfield, ADNR Diane Dunham, Hilcorp i ! MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg -c? ' 3i /i DATE: 3/13/18 P. I. Supervisor FROM: Matt Herrera SUBJECT: Surface Abandonment Petroleum Inspector Stump Lake Unit 41-33RD Hilcorp Alaska PTD 2090100 Sundry 317-416 - 3/11/2018: I travelled to Stump Lake Pad to witness surface P&A including verification of cement to surface, casing cutoff depth compliance, and marker plate information. Hilcorp representative at the location was Cole Bartlewski. All well strings were cemented to surface and topped off prior to marker plate installation. Cutoff depth for marker plate installation was more than 3 feet below - grade. The marker plate had correct information. Attachments: Photos (4) SCANNED • 2018-0311_Surface_Abandon_StumpLake_41-3 3 RD_mh.docx Page 1 of 3 • • • Surface Abandonment— Stump Lake 41-33RD (PTD 2090100) Photos by AOGCC Inspector M. Herrera 3/11/2018 • r. s f-b kx Y. Y ] 4. 4` ' •fit ,r ° 1 cry'_„, � d i .`�. - �" * ' .dam'., �.. , •t 6 :"....k:' ! ;'• ce. , •,f 4.0.."-Y.,,,It * y#+ : at yy . ,: .473': Wbt s. V '4'+ri'`y` • — 2018-0311_Surface_Abandon StumpLake 41 33RD mh.docx Page 2 of 3 • • • �' f I t r . ♦ . t ! ✓. 1 1.,R4, s") ! �". y ► (* !' Aitk "k P 4- ' 1 Moe • t.1 , to e, ,irli IrD} .. � IIII y 1 a+* 1rtt t �� r w.. ..� • i ,:'i'{'.p meb K ,. r 4. '• 'err'; 4114..1 s41' ♦ ' ti e r r- 11.40 b . ''' t Si�46, �� .4M a 'moi ,{Jg}�fix{n}�� ;, 4trI 49t°I 4 )W {x Y a • 2018-0311_Surface_Abandon StumpLake_41-33RD mh.docx Page 3 of 3 � •F Tb • r yw_\��\�Vj, sv THE STATE Alaska Oil and Gas 41 OfA LAsKA. Conservation Commission 4 _-_ y„�x yr= 333 West Seventh Avenue itrt111417.7GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 0..A; FFax: 907.276.7542 www.aogcc.alaska.gov JAN 29L.11 Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Stump Lake Field, Undefined Gas Pool, SLU 41-33RD Permit to Drill Number: 209-010 Sundry Number: 317-608 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Stump Lake Unit has been terminated as of December 1, 2017. An extension to finish final P&A and site clearance on Stump Lake 41-33RD was requested by Hilcorp Alaska, LLC (Hilcorp) in a letter dated December 6, 2017. Initial downhole plugging work has already been completed with cement plugs located throughout the wellbore. As requested by Department of Natural Resources(landowner)in a letter dated December 7,2017 Hilcorp must complete the surface abandonment and site clearance by May 1, 2018 (as allowed per regulation 20 AAC 25.170 (c)). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 2-4--day of January, 2018. pti Tti qw iiMr� t JA!! r.; It� • � aN‘ 1 STATE OF ALASKA2 \� • ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 2017 '"-i3 APPLICATION FOR SUNDRY APPROVALS �' I) 20 AAC 25.280AOGCC 1.Type of Request: Abandon Q• Plug Perforations❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown❑ Suspend 0 Perforate 0 Other Stimulate ❑ Pull Tubing 0 Change Approved Program El Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: 0 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ . 209-010 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service 0 6.API Number: Anchorage Alaska 99503 50-283-20055-01-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A " Will planned perforations require a spacing exception? Yes ElNo Q,/ Stump Lake(SLU)41-33RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0058790 • Stump Lake Unit/Undefined Gas • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,160' , 9,537' • 0' 0' N/A 0' N/A Casing Length Size MD TVD Burst Collapse Structural 77' 30" 77' 77' Conductor Surface 424' 20" 424' 424' 1,530 psi 520 psi Intermediate 2,512' 13-3/8" 2,512' 2,512' 5,380 psi 2,670 psi Intermediate 2,884' 9-5/8" 2,884' 2,884' 6,330 psi 3,810 psi Production 123' 7-5/8" 123' 123' 6,890 psi 4,790 psi Production 5,997' 7" 6,120' 5,506' 7,240 psi 5,410 psi Liner 4,125' 3-1/2" 9,128' 8,505' 10,160 psi 10,540 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: 3-1/2"LS Tubing Grade: L-80 Tubing MD(ft): 5,003' See Attached Schematic See Attached Schematic 1.660"HS L-80 2,986' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"Baker ZXP-N/A 5,003'MD;4,569'TVD-N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: April 15,2018 Commencing Operations: OIL ❑ WINJ 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned Q • 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcoro.com Contact Phone: 777-8420 Authorized Signature: !,/, ,...04,-/ Date: )0/4h 7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,, hh Q r 2-vi G 3 I 1 • Lc V p Plug Integrity I BBOP Test 0 Mechanical Integrity Test ❑ Location Carance 2( /9,n Other: - S'I Lr. 1 �/ - h t' Z".,i' J /v l . i J�J-Ci l y r L.. CG��i�s-� c�4✓��=-atix�L. C`-C is► l-t. t t Post Initial Injection MIT Req'd? Yes 0 No ❑ Spacing Exception Required? Yes ❑ No � Subsequent Form Required: �L - ��" 7 RE3DIVIS ‘, / JAN 2 r 2C18 // APPROVED BY Approved by: 40 i COMMISSIONER THE COMMISSION Date: r2...4- 11 i umu Form anu Form 10- 3 sed/1/2017 e-, Approved application is v lid f r 12 mot R404 AA'' Attachments in Du hcate r/� ,_2-3 -,& I� itaw�� t'`t' p . • Well Prognosis Well: SLU 41-33RD Hilcorp Alaska,LL Date: 12/22/17 Well Name: SLU 41-33RD API Number: 50-283-20055-01 Current Status: SI Gas Well Leg: N/A Estimated Start Date: April 15, 2018 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 209-010 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985)867-0665 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: NA Well Subsurface is Plugged and Abandoned Max. Potential Surface Pressure: NA SLU 41-33RD was Plugged and Abandoned down hole on Sundry Number 317-416 in October 2017. • The surface work could not be completed on this well due to unfavorable tides and winter weather preventing reliable barge traffic. / The surface work remains. Hilcorp has secured agreement from the Department of Natural Resources to allow the completion of the surface work in the Spring of 2018 (See Attached Letter). w� f5r r.z Z.4k 2-5/10 The remainingsurface work is as follows: /�a«��/� (c) Surface-Abandonment Procedures 1. Notify AOGCC 48hrs in advance of cutting wellhead. y /— z3 "/S' 2. Excavate cellar, cut off wellhead and casing 3' below natural GL. 3. Verify that cement is to surface. If cement has fallen down hole on any casing string, perform top job to bring cement to surface. 4. Create well abandonment marker per 20 AAC 25.120. The following must be bead-welded directly to the marker plate: {' a. Hilcorp Alaska, LLC b. PTD: 209-010 c. Well Name: SLU 41-33RD d. API: 50-283-20055-01 5. Install marker plate per 20 AAC 25.120. Collect GPS coordinates. a. Photo document casing cut-off with cement to surface, and Welded Plate installation. 6. Backfill ex avatse out location. �9 Aw' ,.J'its. ,-�J ,'" lie:r1 ' Attachments: '�r ot,, ,......„..4 f.e..,..,...-41-c-ti. � ( -v`4- -a—<- ..,t, 0 1. Actual Schematic 2. Wellhead Diagram 3. DNR Letter dated December 7, 2017 to Hilcorp 4. Hilcorp Letter Dated December 6, 2017 to DNR H . • Stump Lake Unit Well: SLU 41-33RD "-L,.IIf. SCHEMATIC Completion Ran: 3/19/09 PTD: 209-010 API: 50-283-20055-01 CASING DETAIL Description Weight Grade Conn ID Length Top Btm TOC Rotate Hrs RKB to GL=16.80' RKB to MSL=45.10' Structural 30" N/A N/A Weld NA 77' 0' 77' Driven 32.0 hrs Surface 20" 94.08 H-40 BTC 19.124" 424' 0' 424' Surf 77.5 hrs a 1 Intermediate 13-3/8" 72.08 N-80 BTC 12.347" 2,512' 0' 2,512' Surf 240.8 hrs Intermediate 9-5/8" 43.58 N-80 BTC 8.755" 2,884' 0' 2,884' Surf 560.5 hrs 30" ,k!. Production 7-5/8" 29.78 L-80 BTC-Mod 6.875" 123' 0' 123' - 180.0 hrs Production 7" 26.08 L-80 BTC-Mod 6.276" 5,997' 123' 6,120' 2,196' 180.0 hrs Liner 3-1/2" 9.28 L-80 IBT-Mod 2.992" 4,125' 5,003' 9,128' 5,003' 0.0 hrs TUBING DETAIL 4 Tubing 3-1/2" 9.2# L-80 TC-II 2.992" 5,003' 0' 5,003' 20.._J ,1 F Heat String 1.660" 3.028 L-80 BTS-8 1.278" 2,986' 0' 2,986' ' 4.! IJ ? JEWELRY DETAIL 4.4:, No Description Depth Length ID OD 13-3/8 J, e , t 1 Tubing Hanger,Dual FTC-D-DFF6H,3-1/2"MCA,1.900"LI Lift Threads 17.5' 0.97' - 2 Tubing Punch Holes w/cement circulated to surface 10/2017 1,700' - - - 3 7"Baker ZXP packer(set 3/18/09) 5,003' 14.81' 5.250" 6.000" 4 7"x5"Baker Flex-Lock III liner hanger(set 3/18/09) 5,018' 7.30' 5.250" 5.910" 2 5 Baker Model 80-40 Sealbore w/GBH-22 Seal Assembly 5,025' 8.45' 4.000" 5.000" 6 3.5"CIBP w/35 ft of cement on top 10/2017 6,550' 35' - - 7 AD Stop 6,547' 2' 1.500" 2.992" , 8 Slip-Stop,Macco Pack-off,Slip-Stop w/cement SL dump bailed(7/16/09) 8,426' - - - 9 Bridge Plug w/45'cement dump bailed(set 4/5/09) 9,033' 27.87' - - r. 10 PBTD-Top of 3-1/2"Float equipment(tag 3/25/09) 9,093' - _ - - • iui ` 3 .6,iii* PERFORATIONS is",4 • 6 ID Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Gun Size SPF Phase Status Date A Beluga 6,567' 6,567.5' 5,944' 5,944.5' 0.5' 2.0" 4 6/29/2012 10'Pup Joint`, , t > B Beluga 6,576' 6,586' 5,953' 5,963' 10' 2.0" 6 60 deg Isolated 6/29/2012 @ 5,937 a I B Beluga 6,578' 6,578.5' 5,955' 5,955.5' 0.5' 2.0" 4 Isolated 6/29/2012 • ��LLLJ C Beluga 7,502' 7,511' 6,879' 6,888' 9' 2.5" 6 60 deg 7/23/2009 D Tyonek 8,462.5' 8,494' 7,840' 7,871' 30' 2.5" 6 60 deg Isolated 6/21/2009 '..!'• 11 E Tyonek 8,866' 8,880' 8,243' 8,257' 14' 2.5" 6 60 deg Isolated 5/27/2009 7 .., i', B 10'Pup' i'4.; up' Note:Tagged Fill w/GS tool @ 6,561' WLM 06/17/2016 *i, Note:Tagged Fill 1.25"tools @ 7,110' KB on 11/13/2015 *, c Note:Tagged TOC @ 8,355' on 7/22/2009 1 10 Pup Joint r' CEMENT @ 8,406' Casing e+ 1 Size Top Bottom ppg/sx Notes 1F^' l 30" N/A N/A N/A No Cement D 20" Surf. 424' N/A N/A ,Z 13 -r7,1 2 E 13-3/8" Surf. 2,512' N/A N/A 9-5/8" Surf. 2,884' N/A N/A 7-5/8" 2,196' 6,120' 15.8ppg/412sx N/A 7" 5,810' 8,950' 12.Sppg/450sx N/A 9 10 PBTD=0'MD/0'ND TD=10,160'MD/9,537'TVD Max Deviation 49.5°@ 4,670' 6-1/8" Max Dogleg 5.7°/100'@ 3,585' Open Hole Downhole Revised: 11/24/12 Updated by DMA 12-22-17 i . W05/25/estsid2017e-Stump Lake CURRENT WELLHEAD DRAWING SLU 41-33RD Current ilil.•orp Alla4kn.1.1.1: Stump Lake Tubing hanger,Vetco FTC,11" SLU 41-33RD Parent bowl w/mandrel hanger 13 3/8 x 9 5/8 x 7 5/8 x 3%x bushing for heater string,Main 1.660 body 3.720 MCA acme lift x3 34 TC-2 susp,w/3"type H BPV, Heater string mandrel 1.900 U lift x 114 CS Hydril susp pin,1%H BPV Mandrel locks Into parent bowl with lockpins BHTA,Bowen,3 1/8 5M FE X 3"Bowen Union 040 14r, Is, ul o, '44 iniiimi 'Li, - IBJ, T� Q ?� .`"' ^'' Valve,swab,WKM-M, F b q 'OF�1- l. 3 1/8 SM FE,HWO, F,.s2i`elt. .�'S1yo47 ` '0* .‘ ,,' DD Trim )104) loll 2 1/16 5M 3\ ' Heater String mom (rig Valve,upper master, #` 1 .,, WKM-M,3 1/8 5M FE, HWO,DD Trim 6140e .* � Valve,master, i�� ' •.. �. WKM-M,3 1/8 5M FE, 4. ."..-N� HWO,DD Trim Ai, _a�;V fell 1.y. III __ '. III Tubing head,VG-FTC, •' t`�{I 115M X 115 w/8G I . � rt,, ,`,rll, ' bottom,2-2 1/16 5M SSO ,\ kkk • ii, Iii lit Ai! 4 li I laf -'I = 111 Casing spool,FMC-TC60, .:;. 13 5/8 3M X11 5M,w/BG + t"�''' bottom,2-2 1/16 5M SSO ii j �Ilil l� 1�' Ai I 1 - ,� III III I • Double studded packoff, — ' ' 16'''A3MX135/83M,w/ ii �.j 95/8 PP prep —,- { 1a. * Casing head,CIW-WF, ' 1111111 i •/f�/. l 16%3M X 13 3/8"sow,w/ I',l! 3 + 1 ({�V% �i'7ii�.-a'1 2-2 1/16 5M EFO 11! t+ 11' II a 77<-.,OF�w\��'.s. THE STATE Department of Natural Resources F$,�,�.r"t� � of Division of Oil&Gas •:i _-:--':.-Y-:::: '? L ALASIt;A 550 W.7 Avenue,Suite 1100 VIVI IAnchorage,Alaska 99501-3560 GOVERNOR BILL WALKER Main:907.269.8800 Op, � P Fax:907.269.8939 ALAS December 7, 2017 CERTIFIED MAIL RETURN RECEIPT REQUESTED Cody T. Terrell, Landman Hilcorp Alaska,LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Re: Stump Lake Unit Termination Proposal—Approved Dear Mr. Terrell, On December 6, 2017,the State of Alaska, Department of Natural Resources, Division of Oil and Gas (Division)received the Stump Lake Unit Termination Proposal (Proposal)from operator of the Stump Lake Unit(SLU), Hilcorp Alaska, LLC (Hilcorp). This letter approves the Proposal. Hilcorp has been unable to restore production from the SLU and has begun work to plug and abandon the only well within the unit capable of production. The SLU 41-33RD has been plugged to the surface and is no longer capable of production; however the remaining work required by Alaska Oil and Gas Conservation Commission(AOGCC)regulation 20 AAC 25.270,Onshore location clearance,has yet to be completed. Due to weather delays, Hilcorp reports the final work cannot be completed until the spring of 2018. The Division desires the acreage currently held by the SLU to be made available for the spring 2018 Cook Inlet lease sale. So that the area is available for sale,the SLU must terminate and the leases held by the unit allowed to expire or be relinquished. So that the leases may expire or be relinquished without contradicting AOGCC regulation 20 AAC 25.270,Hilcorp has requested DNR approve a time period beyond one year from well abandonment for location clearance, as described in 20 AAC 25.170(c)(1). The terms and timeline for abandonment and rehabilitation are described in the Proposal, and summarized below, are dependent on what, if any, improvements the Division chooses to allow to remain in place. If this area is leased in the upcoming sale it may have an impact on the rehabilitation required by the Division. 1. Hilcorp agrees to terminate the SLU, allowing the oil and gas leases currently held by the SLU to expire. Unit termination would be effective December 1,2017. The leases currently held by the SLU will remain in effect ninety(90)days after Unit termination as provided in 11 AAC 83.140, expiring March 1,2018. This action will allow DNR the opportunity to offer said leases in the 2018 Cook Inlet Lease Sale. 2. Pursuant to 11 AAC 83.140, the leases held by the SLU would continue in full force and effect for not less than 90 days, or no sooner than March 1, 2018. Due to the constraints expressed above, onshore location clearance required under 20 AAC 25.170 cannot be completed prior to March 1, 2018. DNR, as the surface owner and mineral owner of said lands, will grant an extension to Hilcorp to complete the onshore location clearance for the SLU 4 1-33RD Well until May I, 2018. Hilcorp commits to completing the onshore location clearance no later-than May 1, 2018 as part of the surface remediation work for the lease. • • Stump Lake Unit Termination Proposal—Approved December 7,2017 Page 2 of 2 3. Upon receipt of DNR's grant of an extension specified in item 2 above, Hilcorp will submit to AOGCC an Application for Sundry Approvals(Form 10-403)pursuant to 20 AAC 25.170(c) to extend the time for Hilcorp to complete the onshore location clearance activities required under 20 AAC 25.170(a). 4. DNR will provide Hilcorp specific detailed remediation requirements for the remediation of pads,roads, and pipelines located on the surface estate of DNR lands within six(6)months of lease expiration. Hilcorp suggests leaving all pads, roads, and pipelines for future development and to minimize any environmental impacts that the remediation measures may have. 5. Hilcorp will submit to DNR a Remediation Plan within six(6)months of receipt of item 4 specified above. 6. DNR will allow Hilcorp a period of two(2)years, subject to any approved extension thereof, from the date of Hilcorp's Remediation Plan to start the remediation work. Should DNR subsurface become encumbered by an oil and gas lease where Hilcorp has surface improvements, Hilcorp may,upon approval by DNR, transfer all or any portions of roads, pads, and pipelines to the new Lessee for use in their development operations. To the extent the new Lessee and transferee of any roads,pads, and pipelines accepts such assets in their current condition,they will also assume all liability and responsibility for removal of same. Subject to DNR approval,the terms of the transfer may include DNR recognizing the new Lessee as the responsible party and relieving Hilcorp in writing of any further removal obligations under the lease. The AOGCC is the sole authority who may alter the requirements outlined in 20 AAC 25. ,but it is the Division's desire that the Proposal be accepted by the AOGCC as an alternative timeline for abandonment and location clearance. An eligible person affected by this decision may appeal it,in accordance with 11 AAC 02. Any appeal must be received within 20 calendar days after the date of"issuance"of this decision, as defined in 11 AAC 02.040(c)and(d),and may be mailed or delivered to Andrew T. Mack, Commissioner,Department of Natural Resources, 550 W. 7th Avenue, Suite 1400,Anchorage, Alaska 99501; faxed to 1-907-269-8918; or sent by electronic mail to dnr.appeals a,alaska.gov. This decision takes effect immediately.An eligible person must first appeal this decision in accordance with 11 AAC 02 before appealing this decision to Superior Court.A copy of 11 AAC 02 may be obtained from any Department of Natural Resources regional information office. If you have questions regarding this decision,please contact Kevin Pike with the Division at(907) 269-8451 or via email at Kevin.Pike@alaska.gov. Sincerely, tai %; ; .... Chantal Walsh Director • i Post Office Box 244027 Hilcorp Alaska, LLC Anchorage,AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 December 6,2017 Phone:907-777-8432 Fax:907-777-8301 Director Chantal Walsh cterrell@hilcorp.com tiDivision of Oil and Gas Alaska Department of Natural Resources 550 West 7'h Avenue, Suite 1 100 Anchorage,AK 99501 RE: Stump Lake Unit Termination Proposal Dear Director Walsh: Hilcorp Alaska, LLC("Hilcorp")as Operator of the Stump Lake Unit("SLU"),after consultation with land managers at the Department of Natural Resources("DNR''),hereby submits a proposal for the termination of the Stump Lake Unit. This proposal for unit termination is contingent on both Hilcorp and the Department of Natural Resources(`"DNR")meeting certain requirements contained herein. Hilcorp submitted the 2017 Plan of Development and Operations("POD")on March 1,2017. In the POD Hilcorp committed to continue its work over operations for the SLU 41-33RD Well in order to return the SLU to production by the end of the 3'Quarter of 2017. If SLU production failed to return,Hilcorp committed to plug and abandon("P&A")SLU 41-33RD during 2018. As of September 30'h,2017, IIilcorp has been unable to resume production in the SLU. Hilcorp has begun its P&A work on SLU 41-33RD with initial plans to finish the work before January 1,2018. However, the work has not been completed as required by AOGCC regulations(20 AAC 25,Article 2). The SLU 41-33RD Well has been cemented to the surface and is no longer capable of production. The remaining P&A work required by AOGCC is the onshore location clearance as provided under 20 AAC 25.170. Due to permitting and weather delays,onshore location clearance cannot be completed until Spring 2018. DNR has expressed its desires to terminate the SLU, which would cause the SLU leases currently held by the unit to expire. This would allow the acreage to be available in the Spring 2018 Cook Inlet Lease Sale. Hilcorp does not object to unit termination,but we are concerned about Hilcorp's obligations regarding lease expiration. The AOGCC requires onshore location clearance,as provided under 20 AAC 25.170,to be completed for the S1,U 4I-33RD Well before expiration of Hilcorp's underlying oil and gas lease. As stated in the paragraph above,due to permitting and weather delays the onshore location clearance cannot be completed until Spring 2018. The oil and gas lease allows Hilcorp six(6)months from the time of lease expiration to remove all`machinery,equipment,tools,and materials other than improvements needed for producing wells"and further requires us to"deliver up said lands or such portion or portions thereof in good order and condition." It's unclear as to what is considered"good order and condition"of the lands as same is not defined. It's also unclear as to the amount of time Hilcorp has until DNR lands should be returned to DNR in"good order and condition"after lease expiration. Due to the constraints expressed above, it's apparent that six(6)months is not a reasonable amount of time to perform the required remediation measures and vacate the premises. • ! Hilcorp Alaska LLC Stump Lake Unit Termination Proposal Page 2 of 2 With the foregoing taken into consideration, Hilcorp makes the following proposal: 1. Hilcorp agrees to terminate the SLU,allowing the oil and gas leases currently held by the SLU to expire. Unit termination would be effective December 1,2017. The leases currently held by the SLU will remain in effect ninety(90)days after Unit termination as provided in 11 AAC 83.140, expiring March I,2018.This action will allow DNR the opportunity to offer said leases in the 2018 Cook Inlet Lease Sale. 2. Pursuant to 11 AAC 83.140,the leases held by the SLU would continue in full force and effect for not less than 90 days,or no sooner than March 1,2018. Due to the constraints expressed above, onshore location clearance required under 20 AAC 25.170 cannot be completed prior to March 1, 2018. DNR,as the surface owner and mineral owner of said lands,will grant an extension to Hilcorp to complete the onshore location clearance for the SLU 41-33RD Well until May I,2018. Hilcorp commits to completing the onshore location clearance no later than May 1,2018 as part of the surface remediation work for the lease. 3. Upon receipt of DNR's grant of an extension specified in item 2 above,Hilcorp will submit to AOGCC an Application for Sundry Approvals(Form 10-403)pursuant to 20 AAC 25.170(c)to extend the time for Hilcorp to complete the onshore location clearance activities required under 20 AAC 25.170(a). 4. DNR will provide Hilcorp specific detailed remediation requirements for the remediation of pads, roads,and pipelines located on the surface estate of DNR lands within six(6)months of lease expiration. Hilcorp suggests leaving all pads,roads,and pipelines for future development and to minimize any environmental impacts that the remediation measures may have. 5. Hilcorp will submit to DNR a Remediation Plan within six(6)months of receipt of item 4 specified above. 6. DNR will allow Hilcorp a period of two(2)years,subject to any approved extension thereof,from the date of Hilcorp's Remediation Plan to start the remediation work.Should DNR subsurface become encumbered by an oil and gas lease where Hilcorp has surface improvements, Hilcorp may,upon approval by DNR,transfer all or any portions of roads,pads,and pipelines to the new Lessee for use in their development operations.To the extent the new Lessee and transferee of any roads,pads,and pipelines accepts such assets in their current condition,they will also assume all liability and responsibility for removal of same.Subject to DNR approval,the terms of the transfer may include DNR recognizing the new Lessee as the responsible party and relieving Hilcorp in writing of any further removal obligations under the lease. Please provide a response at your earliest convenience. Should you have any further questions, please contact the undersigned at(907-777-8432). Sincerely, Cody T.Terrell.Landman HILCORP ALASKA, LLC • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, January 23, 2018 10:20 AM To: 'Ted Kramer' Cc: Cody Terrell; Donna Ambruz Subject: RE: Stump Lake 41-33RD P&A Surface Extension/Waiver Ted, I looked at the letter a that DNR sent to you dated December 7, 2017. It appears they are requiring a final site abandonment by May 1st. AOGCC has to comply with landowner request per 20 AAC 25.170(b)and specify the same date for the final site clearance. Call me to discuss. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Ted Kramer [mailto:tkramer@hilcorp.com] Sent: Monday,January 22,2018 10:16 AM To:Schwartz, Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Cody Terrell<cterrell@hilcorp.com>; Donna Ambruz<dambruz@hilcorp.com> Subject:Stump Lake 41-33RD P&A Surface Extension/Waiver Guy, Hilcorp is asking for a 4 month extension/waiver to complete the surface P&A work on the above well. Hilcorp is requesting this Waiver from 20 AAC 25.170(a). History The Stump Lake Lease is set to expire on March 1, 2018. Hilcorp completed the down-hole P&A of the above well on October 20, 2017. Hilcorp was unable to complete the surface location work due to a tidal induced water flow that prevented the digging up the cellar to complete the surface abandonment without additional permitting. This permitting is now in place but Hilcorp is unable to barge the necessary equipment across the inlet due to ice pans in the Cook Inlet. Hilcorp asks for a four month extension from the March 1st deadline to complete this work(until July 1, 2018). Sincerely, i Ted Kramer Sr.Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 2 • OFT I/77 THE STATE Alaska Oil and Gas °fLASKA Conservation Commission titz 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®� dale/1J" Fax 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager SCANNED S E? 0 12.01? Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Stump Lake Field, Undefined Gas Pool, SLU 41-33RD Permit to Drill Number: 209-010 Sundry Number: 317-416 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy Foerster Commissioner S-I' DATED this 3! day of August, 2017. RBDMS 6t-' A 3 3 1 2017 . STATE OF ALASKA IV ED rt ALASKA OIL AND GAS CONSERVATION COMMISSION / tl`. 2 9 017 APPLICATION FOR SUNDRY APPROVALS %3j UU /7 20 AAC 25.280 1.Type of Request: Abandon Q • Plug Perforations❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown❑ Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska, LLC Exploratory 0 Development Q' 209-010 ' 3.Address: 3800 Centerpoint Dr,Suite 14006.API Number P Stratigraphic 0 Service 0 Anchorage Alaska 99503 50-283-20055-01-00 ' 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? N/A ' Stump Lake(SLU)4133RD - Will planned perforations require a spacing exception? Yes 0 No DI 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0058790 Stump Lake Unit/Undefined Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,160' - 9,537' + 8,426' ` 7,806' . -1,513 psi 9,033' 6,561'(Patch) Casing Length Size MD TVD Burst Collapse Structural 77' 30" 77' 77' Conductor Surface 424' 20" 424' 424' 1,530 psi 520 psi Intermediate 2,512' 13-3/8" 2,512' 2,512' 5,380 psi 2,670 psi Intermediate 2,884' 9-5/8" 2,884' 2,884' 6,330 psi 3,810 psi Production 123' 7-5/8" 123' 123' 6,890 psi 4,790 psi Production 5,997' 7" 6,120' 5,506' 7,240 psi 5,410 psi Liner 4,125' 3-1/2" 9,128' 8,505' 10,160 psi 10,540 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: 3-1/2"LS Tubing Grade: L-80 Tubing MD(ft): 5,003' See Attached Schematic I See Attached Schematic 1.660"HS L-80 2,986' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"Baker ZXP-N/A - 5,003'MD;4,569'TVD-N/A 12.Attachments: Proposal Summary a Wellbore schematic ❑j 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic 0 Development Q• Service 0 14.Estimated Date for 15.Well Status after proposed work: t--t Commencing Operations: September 8,2017 OIL 0 WINJ 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ El Op Shutdown ❑ Abandoned Q. 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerl hllcorp.cant ,�� Contact Phone: 777-8420 Authorized Signature: Cr'� `' fi Date: /t//7 QQQ COMMM[ISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Sr7— `0(42 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance KI Other: c,Ai-rERw'•-C Q:.u.c_ QL.Ac.e'-rAEV-3Ance.„&veb PEAL 20 Aye-2S,I 1 w� Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes ❑ No lJ Subsequent Form Required: lo_4®� RBDMS V —1 AJj j 1 2017 C4/ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: g —3( /7Suomn Form rwor 10vis d 4/ 017 r li o�is valid for 12 months from the date of approval. Attachments in Duplicate ,� � $�3� ��- 0Rtett eili1ri • • • Well Prognosis Well: SLU 41-33RD Hilcorp Alaska,LL, Date:08/29/17 Well Name: SLU 41-33RD API Number: 50-283-20055-01 Current Status: SI Gas Well Leg: N/A Estimated Start Date: September 8th, 2017 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 209-010 First Call Engineer: Ted Kramer (907)777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: –2,282 psi. @ 7,692' TVD (Based on 2009 Pressure Survey) Max. Potential Surface Pressure: – 1,513 psi - (Subtract 0.1 psi/ft. for gas) Brief Well Summary SLU 41-33RD was drilled by Chevron in February 2009,attempting to target the Tyonek sands that were perforated in the original wellbore. The Tyonek sands were determined to be wet, but backup Beluga targets were successfully perforated uphole at 7,502' MD. After three years of production, additional perforations were added between 6,567' and 6,586' MD. These brought sand and water into the wellbore,which ultimately killed the lower perforations. Attempted remediation's included slickline bailing and a coiled tubing cleanout/ N2 lift, neither of which were successful. The well has now been shut in for an extended period with no plans to fix or sidetrack, as the remaining reserves do not justify the cost to bring it back online. This program is intended to fully plug and abandon SLU 41-33RD. 1 3 Cana t 10o Abandonment Procedure 1. Pressure test IA and OA to 1,500 psi to confirm integrity. t/ 2. Check well head to verify cement to surface in the 13-3/8"x9-5/8" annulus by shining a flashlight in through the casing valve. Note: If test is inconclusive, move on to step#2 but note to hot tap 13- 3/8" casing string prior to cutting off well head to check for gas accumulation. 3. Provide 24-hr notice to AOGCC that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 112.(h). E- line 4. RU E-Line, PT lubricator to 2000 psi (high) and 250 psi (low). 5. PU, RIH W/2.70" GR. Drift to top of fill at 6,561' MD. a. If GR does not get down below 6,000', commence bailing operations with slickline to 6,000'. Note: Hilcorp asks for a variance from 20 AAC.25.112(c)(1)(E) if the plug is set above 6,517' (>50' above the top perf). PCu- `2t? AAL 'is, 114_0 6. PU Cast Iron Bridge Plug and RIH. Set 3.5" CIBP at 6,550' MD or as deep as possible below 6,000'. • • Well Prognosis Well: SLU 41-33RD Hilcorp Alaska,LL' Date:08/29/17 7. Dump bail 25'of cement on top of bridge plug. 8. WOC overnight. 9. PU Blind Box. RIH and tag TOC. POOH. 10. PU Tubing Punch guns. RIH W/Same and punch tubing and 7" casing from 1,700 to 1,710' MD. 11. RD E-Line. Test Pump 12. RU Test Pump and return tank. Pump down tubing string and take returns up a. Heater String b. OA c. IA Measure flow returns from each string. Goal is to achieve at least 2 bbl./min. return from each string by pumping water down tubing and measuring the returns up each string with either a bucket test or with a flow meter. Monitor the pressure response of each side during test. 13. Shut in all strings and RU chart recorder. Test casing integrity by pressuring up on all casing strings at the same time (jug test)to 1,500 psi and chart for 30 min. 14. RD Test Pump Cement 15. MIRU Cement Van, return tank, and flow back iron. 16. Rig up to pump into Heater String.Open tubing to take returns and pump water to verify good circulation of at least 2 bpm. 17. Pump 5 barrels of 15.8 ppg Class G cement down heater string to fill to surface. Circ. Cement line clean and RD cement line move it to tubing string. Line up to take returns up the OA(13-3/8" X 7"Annulus) . 18. Verify that there is still at least 2 BPM circulating rate up both the OA and the IA. 19. Open the flow path down the tubing and up the OA. Pump cement down the tubing and up the OA until cement is circulated to surface out of the OA. Open the IA and close the OA and pump cement up the IA to surface. Shut down,WOC. Note: Total Volume required will be 148 bbls of cement,; 84 bbls of cement(including 50%excess) for the OA, plus 64 bbls of cement for the IA(including 50%excess). Post-Abandonment Procedures 1. Notify AOGCC 48hrs in advance of cutting wellhead. 2. Hot tap 13-3/8" casing 180 deg from casing valve to ensure there is not gas build up in the casing string. 3. Excavate cellar,cut off wellhead and casing 3' below natural GL. 4. Verify that cement is to surface. If cement has fallen down hole on any casing string, perform top job to bring cement to surface. / 5. Create well abandonment marker per 20 AAC 25.120. The following must be bead-welded directly to the marker plate: a. Hilcorp Alaska, LLC b. PTD: 209-010 c. Well Name: SLU 41-33RD d. API: 50-283-20055-01 • • Well Prognosis Well: SLU 41-33RD Hilcorp Alaska,LL Date:08/29/17 6. Install marker plate per 20 AAC 25.120. Collect GPS coordinates. a. Photo document casing cut-off with cement to surface, and Welded Plate installation." 7. Backfill excavation, close out location. ,/ Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Wellhead Diagram Stump Lake Unit 111 0 ACTUAL SCHEMA Well: SLU41-33RD • 1°''' '" "°'" Completion Ran: 3/19/09 PTD: 209-010 API: 50-283-20055-01 CASING DETAIL Description Weight Grade Conn ID Length Top Btm TOC Rotate Hrs RKB to GL=16.80' RKB to MSL=45.10' Structural 30" N/A N/A Weld NA 77' 0' 77' Driven 32.0 hrs Surface 20" 94.0# H-40 BTC 19.124" 424' 0' 424 Surf 77.5 hrs Intermediate 13-3/8" 72.08 N-80 BTC 12.347" 2,512' 0' 2,512' Surf 240.8 hrs Intermediate 9-5/8" 43.5# N-80 BTC 8.755" 2,884' 0' 2,884' Surf 560.5 hrs so Production 7-5/8" 29.7# L-80 BTC-Mod 6.875" 123' 0' 123' - 180.0 hrs Production 7" 26.08 L-80 BTC-Mod 6.276" 5,997' 123' 6,120' 2,196' 180.0 hrs , Liner 3-1/2" 9.2# L-80 IBT-Mod 2.992" 4,125' 5,003' 9,128' 5,003' 0.0 hrs TUBING DETAIL Tubing 3-1/2" 9.2# 1-80 TC-ll 2.992" 5,003' 0' 5,003' 20 J Heat String 1.660" 3.02# L-80 BTS-8 1.278" 2,986' 0' 2,986' 467Bowl ' ' I.. . JEWELRY DETAIL l " - - No Description Depth Length ID OD 13-3/8 ,, 1 Tubing Hanger,Dual FTC-D-DFF6H,3-1/2"MCA,1.900"Ll Lift Threads 17.5' 0.97' 2 7"Baker ZXP packer(set 3/18/09) 5,003' 14.81' 5.250" 6.000" 9-5/8 " 3 7"x5"Baker Flex-Lock Ill liner hanger(set 3/18/09) 5,018' 7.30' 5.250" 5.910" "y 4 Baker Model 80-40 Sealbore w/GBH-22 Seal Assembly 5,025' 8.45' 4.000" 5.000" 5 AD Stop 6,547' 2' 1.500" 2.992" 4i!' 6 Slip-Stop,Macco Pack-off,Slip-Stop w/cement SL dump bailed(7/16/09) 8,426' - - - 4 7 Bridge Plug w/45'cement dump bailed(set 4/5/09) 9,033' 27.87' - - ta i'A 8 PBTD-Top of 3-1/2"Float equipment(tag 3/25/09) 9,093' - - - !,,.1 PERFORATIONS & ID Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Gun Size SPF Phase Status Date 3 A Beluga 6,567' 6,567.5' 5,944' 5,944.5' 0.5' 2.0" 4 6/29/2012 B Beluga 6,576' 6,586' 5,953' 5,963' 10' 2.0" 6 60 deg Isolated 6/29/2012 4 B Beluga 6,578' 6,578.5' 5,955' 5,955.5' 0.5' 2.0" 4 Isolated 6/29/2012 If C Beluga 7,502' 7,511' 6,879' 6,888' 9' 2.5" 6 60 deg 7/23/2009 10' @ 5 up Joint —� D Tyonek 8,462.5' 8,494' 7,840' 7,871' 30' 2.5" 6 60 deg Isolated 6/21/2009 7 l4 E Tyonek 8,866' 8,880' 8,243' 8,257' 14' 2.5" 6 60 deg Isolated 5/27/2009 . _,� A Note:Tagged Fill w/GS tool @ 6,561' WLM 06/17/2016 5 B 10'Pup Joint Note:Tagged Fill 1.25"tools @ 7,110' KB on 11/13/2015 ©6,718' CEMENT 10'Pup Joint '' - Casing @ 7,652' "' Size Top Bottom ppg/sx Notes C 30" N/A N/A N/A No Cement 20" Surf. 424' N/A N/A 13-3/8" Surf. 2,512' N/A N/A 9-5/8" Surf. 2,884' N/A N/A 7-5/8" 2,196' 6,120' 15.8ppg/412sx N/A `� :' 7" 5,810' 8,950' 12.5ppg/450sx N/A 10'Pup Joint =�"" .�., @ a,aos "" Note:Tagged TOC @ 8,355' on 7/22/2009 D ' E fl 7 8 .) ' PBTD=8,426'MD/7,806'ND • • TD=10,160'MD/9,537'ND ^ 6-1/8" Max Deviation 49.5°@ 4,670' Open Hole,,. Max Dogleg 5.7"/100'@ 3,585' Downhole Revised: 11/24/12 Updated by CAH 08-28-17 n • Stump Lake Unit Well: SLU 41-33RD • nakurp Alaska,LLC P OPOSED SCHEMATIC Completion Ran: 3/19/09 PTD: 209-010 API: 50-283-20055-01 CASING DETAIL Description Weight Grade Conn ID Length Top Btm TOC Rotate Hrs RKB to GL=16.80' Structural 30" N/A N/A Weld NA 77' 0' 77' Driven 32.0 hrs RKB toMSL=45.10' Surface 20" 94.04* H-40 BTC 19.124" 424' 0' 424' Surf 77.5 hrs � . 1 Intermediate 13-3/8" 72.08 N-80 BTC 12.347" 2,512' 0' 2,512' Surf 240.8 hrs Intermediate 9-5/8" 43.5# N-80 BTC 8.755" 2,884' 0' 2,884' Surf 560.5 hrs 30" Production 7-5/8" 29.7# L-80 BTC-Mod 6.875" 123' 0' 123' - 180.0 hrs Production 7" 26.0# L-80 BTC-Mod 6.276" 5,997' 123' 6,120' 2,196' 180.0 hrs s- Liner 3-1/2" 9.28 L-80 IBT-Mod 2.992" 4,125' 5,003' 9,128' 5,003' 0.0 hrs M ,1' TUBING DETAIL • Tubing 3-1/2" 9.28 L-80 TC-II 2.992" 5,003' 0' 5,003' 20 t :$ : '� Heat String 1.660" 3.02# L-80 BTS-8 1.278" 2,986' 0' 2,986' JEWELRY DETAIL "" py" No Description Depth Length ID OD 13-3/8 ^ 1 Tubing Hanger,Dual FTC-D-DFF6H,3-1/2"MCA,1.900"IJ Lift Threads 17.5' 0.97' - - 2 Tubing Punch Holes w/cement circulated to surface ±1,700' ,I , t 3 7"Baker ZXP packer(set 3/18/09) 5,003' 14.81' 5.250" 6.000" 4 7"x5"Baker Flex-Lock Ill liner hanger(set 3/18/09) 5,018' 7.30' 5.250" 5.910" 1*r 5 Baker Model 80-40 Sealbore w/GBH-22 Seal Assembly 5,025' 8.45' 4.000" 5.000" il 2 6 3.5"CIBP w/35 ft of cement on top ±6,550' 35' 7 AD Stop 6,547' 2' 1.500" 2.992" 8 Slip-Stop,Macco Pack-off,Slip-Stop w/cement SL dump bailed(7/16/09) 8,426' 9 Bridge Plug w/45'cement dump bailed(set 4/5/09) 9,033' 27.87' - - 10 PBTD-Top of 3-1/2"Float equipment(tag 3/25/09) 9,093' - - - 3 PERFORATIONS � � II ,• 4 i' •' t 5 ID Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Gun Size SPF Phase Status Date A Beluga 6,567' 6,567.5' 5,944' 5,944.5' 0.5' 2.0" 4 6/29/2012 10'Pup Joint B Beluga 6,576' 6,586' - 5,953' 5,963' 10' 2.0" 6 60 deg Isolated 6/29/2012 B Beluga 6,578' 6,578.5' 5,955' 5,955.5' 0.5' 2.0" 4 Isolated 6/29/2012 @ 5,93 C Beluga 7,502' 7,511' 6,879' 6,888' - 9' 2.5" 6 60 deg 7/23/2009 is D Tyonek 8,462.5' 8,494' 7,840' 7,871' 30' 2.5" 6 60 deg Isolated 6/21/2009 #,. 6 E Tyonek 8,866' 8,880' 8,243' 8,257' 14' 2.5" 6 60 deg Isolated 5/27/2009 ',3 a'5 7 - B 10'Pup Joint ' ! Note:Tagged Fill w/GS tool @ 6,561'WLM 06/17/2016 @6,718' I; 3 IP�y ��> Note:Tagged Fill 1.25"tools @ 7,110' KB on 11/13/2015 a... c Note:Tagged TOC @ 8,355'on 7/22/2009 III l ill:, 8 10'Pup Joint ,;,. CEMENT @ 8,406' ' Casing .';� Size Top Bottom ppg/sx Notes 30" N/A N/A N/A No Cement D 20" Surf. 424' N/A N/A E 13-3/8" Surf. 2,512' N/A N/A .yl 9-5/8" Surf. 2,884' N/A N/A 7-5/8" 2,196' 6,120' 15.8ppg/412sx N/A 7" 5,810' 8,950' 12.5ppg/450sx N/A 9 777 10 PBTD=0'MD/0'TVD 7 _Al' IL TD=10,160'MD/9,537'TVD 6-1/8" Max Deviation 49.5°@ 4,670' Open Hole Max Dogleg 5.77100'@ 3,585' Downhole Revised: 11/24/12 Updated by DMA 08-24-17 . • Westside-Stump Lake • CURRENT WELLHEAD DRAWING SLU 41-33' Current 05/25/2017 flikorp Aka*,IJA Stump Lake Tubing hanger,Vetco FTC,11" SLU 41-33RD Parent bowl w/mandrel hanger 13 3/8 x 9 5/8 x 7 5/8 x 3 i4 x bushing for heater string,Main 1.660 body 3.720 MCA acme lift x3 TC-2 susp,w/3"type H BPV, Heater string mandrel,1.900 IJ lift x 1'''A CS Hydril susp pin,1'A H BPV Mandrel locks into parent bowl with lockpins BHTA,Bowen,3 1/8 5M FE X 3"Bowen Union L 1-04rrxi ., o' "0 0111.0111111011.1 1?'',sG�• OS��e 4 "' Valve,swab,WKM-M, trc,cy, ,) O^'cF 17, '414.1-R, � \ .I 31/85M FE,HWO, �,�?7FFIZ,�� -.5. �O 2j Yi DD Trim r� � pie 2 1/16 SM " Heater String j Valve,upper master, 0/-0\ ,, WKM-M,3 1/8 5M FE, HWO,DD Trim � � ' >; .40 Valve,master, � WKM-M,3 1/8 5M FE, :'Sp A HWO,DD Trim - - ' ...., 1111.07%,...110„...4-.4.10110:0-i-. ...s. ....1 1' tell§. !.1 _ � EI lei Tubing head,VG-FTC, - 1 i,,' 1 uw 6 I _ ddir 11 5M X11 5M w/BG l _ ' yl! llh bottom,2-2 1/16 5M SSO - 1 111. � MI i tat = _ Casing spool,FMC-TC60, 13 5/8 3M X11 5M,w/BG (E:4,-111 �[Q _� bottom,2-2 1/16 5M SSO _I uIIII 111 ` l N.7 lit it In Double studded packoff, 15 16%3MX135/83M,w/ � 9 5/8 PP prep • '1 i } - 9 Casing head,CIW-WF, it i 16%3M w/X1338"sow, f` 2-2 1/16 5M EFO ,�c: l.'!11%,s,, ,' 4MI-i•': I I . STATE OF ALASKA ALI,OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations U Fracture Stimulate LI Pull Tubing❑ Operations shutdown J Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well❑ Other: Remove/Replace Patch ❑✓ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Developments Exploratory ❑ 209-010 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-283-20055-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0058790 Stump Lake Unit(SLU)41-33RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Stump Lake Unit/Undefined Gas 11.Present Well Condition Summary: RECEIVED Total Depth measured 10,160 feet Plugs measured 9,033 feet true vertical 9,537 feet Junk measured 6,561 (fill) feet JUL 12 2016 Effective Depth measured 6,561 feet Packer measured 5,003 feet A/' GCC true vertical 5,939 feet true vertical 4,586 feet p��-�iill�aj,� Casing Length Size MD TVD Burst Collapse Structural 77' 30" 77' 77' Conductor Surface 424' 20" 424' 424' 1,530 psi 520 psi Intermediate 2,512' 13-3/8" 2,512' 2,512' 5,380 psi 2,670 psi Intermediate 2,884' 9-5/8" 2,884' 2,884' 6,330 psi 3,810 psi Production 123 7-5/8" 123 123' 6,890 psi 4,790 psi Production 5,997' 7" 6,120' 5,506' 7,240 psi 5,410 psi Liner 4,125' 3-1/2" 9,128' 8,505' AUG10,160 psi 10,540 psi Perforation depth Measured depth See Attached Schematic SCANNED G 1 0 LU IU True Vertical depth See Attached Schematic 3-1/2"LS L-80 5,003'MD 4,586'TVD Tubing(size,grade,measured and true vertical depth) 1.660"HS L-80 2,986'MD 2,986'TVD 5,003'MD Packers and SSSV(type,measured and true vertical depth) 7"Baker ZXP 4,586'TVD N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 9 Subsequent to operation: 0 0 0 50 9 14.Attachments(required per 20 AAC 25,070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations s Exploratory Ll Developments Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas 0 WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Li WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-728 Contact Joe Kaiser-777-8393 Email jkaiser@hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature 7 Phone 907-777-8405 Date 7/11/1 (;• Fusin 10-404 RcviaeU 5/2015 .ta &LniiitO,,iynial Oily '7'7''6' RBDMS LL-- JUL 1 3 2016 ,A(.7/zo7/6 • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SLU 41-33RD Wireline 50-283-20055-01-00 209-010 12/22/15 6/17/16 Daily Operations: 12/22/2015-Tuesday Arrive Beluga. Start equipment and travel to Stump Lake. PTW and JSA. Spot equipment and rig up lubricator. Pressure test to 250 psi low and 2,500 psi high.TP- 2 psi. RIH w/3" GS to 6,603' WL w/t latch jar 8X shear tool POOH. Add 5' stem. RIH w/same to same w/t latch jar 10X shear tool POOH. RIH w/same to same latch tool jar 5X. Looked like a stop came free. POOH and had the 3-1/2" A-stop. Rig for stand by and rebuild GS tool. Will pull patches and AD2 Stop in am. 12/23/2015 -Wednesday Meet at office. PTW and JSA. Mobe to Stump Lake. Arrive @ Stump Lake, rig up. RIH w/3" GS to 6,604' WL, pull patch, get blown up hole, top wire out @ 6,520', pull to 6,500' WLM and tools became stuck. Called town and discussed. Worked tools and waited on cutter bars from town. Wire came free and moved it up to+/-6478' (top tool string). Drop 1-1/2" cutter bar, weight 20 minutes, whip wire, no cut. Drop 1-3/4" cutter bar, cut wire, POOH, change to 2-1/4" stem, 1-3/4 KJ, 1-1/2 OJ, 1-1/2 SSSJ. RIH w/2"JDC to 6,404' KB, latch cutter bar, POOH. RIH w/ JDC and pull other cutter bar. SDFN. Got both cutter bars out hole. 12/24/2015-Thursday Morning safety meeting, sign permits, go over plan for the day. RIH w/2.8 Wire finder, 3' of stem, 2.8 LIB, to 6,413' WL, tag, POOH, OOH w/inconclusive marks. RIH w/2.8 Wire finder, 3" GU, 2.7 Bait sub w/2.8 4 prong wire grab to 6,413', jar 5 times, come free, pooh w/ 14' of wire. RIH w/same to 6420' WL Jar 5x come free, POOH, OOH w/ no wire. RIH w/ same to 6,421' WL, w/t jar 3 times, come free, POOH, OOH w/no wire. RIH w/2.7 Wire finder, 3' of stem, 2.75 LIB to to same, POOH, OOH w/ inconclusive marks. RIH w/2.7 wire finder, 3' of stem, 3" GU w/2.7 Bait sub w/XO (1.375 fishing neck) below. w/2.6 3 prong grab (1.75 fishing neck), to 6,423', beat down, latch,jar 4 times, shear off. Leave grab and bait sub in hole. Rig down, head back to camp. 05/05/2016-Thursday Depart shop and arrive Beluga. PTW and JSA. Depart to location. Rig up lubricator and pressure test to 2,500 psi. RIH w/2.75" LIB to 6,389'. Hit down once and POOH. Fishing neck imprint showed on the LIB. RIH w/GR to 6,389', latch, 4 jar licks at 3,000 lbs and came free. POOH with baited grab and no wire. SDFN. 05/06/2016- Friday PTW and JSA. Mobe to location, PT to 250 psi low and 2,500 psi high. RIH w/2.50" LIB to 6,396', work tools and POOH. RS impression. RIH w/2.3" blind box to 6,396' W/T- no gain. POOH. RIH w/2.75" LIB to 6,383 WL. W/T, POOH, had wire impressions. RIH w/ baited 3 prong wire grab w/GR to 6,383' WL. Grab wire and hit jars 6 times at 3,000 lbs and came free. POOH with 1-1/2' wire. RIH w/same and hit jars 7 times and came free. POOH w/no wire. RIH w/2.75" LIB and POOH showed wire impressions. Rig for stand-by SDFN. 05/07/2016-Saturday PTW and JSA. Depart to Stump Lake. Swap from braided line to 1.25" SL. P/T 250 psi low and 2,500 psi high. RIH w/baited 2-prong grab w/GR to 6,424'WLM, WT and POOH with 30' 1.25" wire. RIH w/2.75" LIB to 6,435'. Get impression, POOH w/clear RS and wire impressions. RIH w/baited 2-prong grab w/GR to 6,435' WLM, WT and POOH with no wire. RIH w/2-1/2"JUS to 6,434' WL, WT, latch and shear off. Swap back to braided line. RIH to 1,800', saw loose strands, pull out of hole and re-head. RIH w/2-1/2"JDC to 6,398' BL-latch -work tools with 5,000 lb jar licks for 1 hr and came loose. POOH -sheared pin. SDFN. Fluid level 5,400'. TP- 60 psi. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SLU 41-33RD Wireline 50-283-20055-01-00 209-010 12/22/15 6/17/16 Daily Operations: 05/08/2016-Sunday PTW and JSA. Depart to Stump Lake. Swap from braided line to 1.25" SL. P/T 250 psi low and 2,500 psi high. RIH w/2- 1/2"JDC to 6,365' WT- latch -WT at 4,500 lb jar licks for 1-1/2 hrs-came free- no wire.. RIH w/same to 6,365' BL-WT- latch -wt at 4,500 lbs for 1-1/2 hrs and shear off. POOH. Lay down and move mask truck re-head and standby for link belt crane. Have a JSA with new crane operator and start rig up. RIH w/2.35" HD-JDC to 6,365' BL WIT- latch -W/T up to 7,000 lbs for 1 hour and shear off. POOH. RIH w/same wit to 7,400 lbs for 1 hr and shear off. Lay lub down, cut wire/re-head, swap 1-3/4" stem for one 2" and one 2-1/8" stem. SDFN TP- 10 psi. 05/09/2016- Monday PTW and JSA. Mobe to location, PT to 250 psi low and 2,500 psi high.Add stick of lub and retest. RIH w/ HD-JDC to 6,367' BL- latch-W/T for 1-1/2 hrs and shear off. POOH. Re-head and cut wire. Add 2.5" x 10' wt bar. RIH w/same to 6,367" - latch -WT for 2 hrs and came free 8,400 lbs. POOH, noting every 30' collar. Have missing fish minus bottom assy of GS. Change stem back to original - re-head. RIH w/2.75" LIB and get impression of. RIH w/2 prong wire grab w/GR to 6,381' -WT-came free. POOH and no wire. SDFN. TP- 10 psi. 05/10/2016-Tuesday PTW and JSA. Mobe to location, drop 1 stick of lub. PT to 250 psi low and 2,500 psi high. RIH w/2.50" LIB to 6,420' WL- get impression - POOH -clear wire impressions. Rig up vac truck&triplex to begin jugging/flushing well - pressure up to 1,500 psi after 55 bbls. RIH w/4 prong wire grab to 6,420'WL. Wire kept slipping off. Made 5 runs with 4, 2 spear, 2 and 3 prong w/GR. Wire kept slipping off. RIH w/2.50" LIB to 6,420' WL-get impression w/wire impressions. RIH w/2.50" magnet to 6,420' - POOH - no significant return. RIH w/ 1.905" GR w/2.50" cent to 6,420' -W/T- no gain - POOH. RIH w/ 1.50" blind box to 6,420' -W/T- no gain - POOH -considerable damage to blind box. SDFN. TP- 10 psi. 05/13/2016- Friday Arrive @ Stump Lake, perform JSA, gain permit approval, begin rig up. Pressure test 250-2,500psi, tests good. RIH w/ baited 1 prong WG w/GR to 6,420' WL W/T, no latches. POOH w/ no wire. RIH w/baited wire spear w/GR to 6,420' WL W/T, no latches. POOH w/no wire. RIH w/baited pocket broach. Spear w/GR to 6,420' WL W/T, latch. Pull three 900#JL and came free. POOH w/no wire. RIH w/ PR to 6,397' WL, sit early, WIT, no latch. POOH. RIH w/ PR to 6,397' WL, sit early, W/T, no latch. POOH. RIH w/2.50" LIB to 6,420' WL W/T. POOH w/wire impression. RIH w/baited 2 prong WL grab w/GR to 6,390' WL W/T to 6,418' WL, no latches. POOH, no wire. Begin laying down. Secure equipment for the night. 05/14/2016-Saturday Arrive @ Stump Lake, begin stand up. RIH w/2.0" LIB w/2.50" centralizer to 6,420' WIT. POOH w/GS&wire impressions. RIH w/ PR w/2.5" centralizer to 6,420' W/T. Latch W/T, no upward progression, shear off, POOH. RIH w/ centralized 2.3" blind box to 6,420' W/T. No downward progression, POOH. RIH w/2 prong wire grab w/2-1/2"JUC to 6,420' W/T, no snags. POOH w/no wire. RIH w/ PR to 6,420' WL WIT, no latch. POOH w/sheared pin. RIH w/same to 6,420' WIT. Latch W/T @ 1,300#and came free. POOH w/ broken dogs. RIH w/center spear to 6,420' WL W/T. Latch 2 1000#jar licks and came free. POOH, no GS. Begin rig down, secure equipment for standby. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SLU 41-33RD Wireline 50-283-20055-01-00 209-010 12/22/15 6/17/16 Daily Operations: 06/01/2016-Wednesday On location begin rig up, PT lub 2,500#-test good. RIH w/3" GR w/collect pulling tool, to 6,420' KB wt/latched 7 jar licks @ 1,200#came free. POOH, pin sheared on GR. RIH w/3" GR to 6,419' KB. Latched w/t, 12 jar licks @ 1,200# came free. POOH. Pin sheared on GR. Rig down, secure well. 06/13/2016- Monday Arrive Beluga meet w/production TGSA JSA permit. Arrive Stump Lake pad, rig up braided line PT lub 2,500psi, good. RIH w/3" GS to 6,375' WLM. Latch w/tool several jar licks, 5,000#to 7,000#, came free. Hung up @ 6,341' WLM, w/ tool came free. POOH w/bait, sub-spear& GS body 1 piece. Wire 2" no core on GS. RIH w/2.72" lib to 6,349' WLM, hit 2 times, POOH w/impression of wire. RIH w/2-1/2" RB baited w/3 prong wire, grab to 6,349' WLM w/tool to 6,410' WLM w/tool. POOH dragging weight, hung up @ 6,380' WLM 2 jar licks, came free. POOH w/5 pieces. Wire approx. 2' long. RIH w/2.75" lib to 6,412' WLM, hit 2 times. POOH w/impression of wire. RIH w/2-1/2"JUC baited w/ 3 prong wire, grab to 6412'WLM w/tool 3 jar licks, came free. POOH, no wire. LD lub. Secure well for night and return to camp. 06/14/2016-Tuesday Safety meeting,JSA Permit. Arrive Stump Lake. Rig up slickline, P/T 2,500 psi,good. RIH w/2.5" Lib to 6,448' WLM. Hit 2 times, POOH w/impression of wire & GS core. RIH w/2.35" overshot, baited w/2-1/2"JUC to 6,448' WLM w/tool, latch 3 jar licks. Came free, POOH, pin sheared. RIH w/2-1/2"JDC to 6,451' WLM w/tool, several jar licks, came free. POOH w/GS core. RIH w/2.75" Lib to 6,100' WLM. Sit w/tool, would not pass. POOH, wire marks. RIH w/3-prong wire grab baited w/2-1/2"JUC to 6,108' WLM w/tool to 6,124' WLM. POOH w/2 pieces wire, 2'total. RIH w/same to 6,452' WLM. No obstruction. POOH. RIH w/2.75" Lib to 6,452' WLM. Sit hit 1 time. POOH w/ impression of wire. RIH w/single prong wire grab baited w/2-1/2"JUC to 6,451' WLM w/tool. Several friction bites. POOH. RIH w/2.70" blind box to 6,452' WLM w/tool. POOH. OOH, LD Lub. Secure well for night. 06/15/2016-Wednesday PTW and JSA. Cut wire re-head, check tool string. RIH w/2 prong wire grab baited w/2-1/2"JUC to 6,450' WLM w/tool to 6,459' WLM, would not latch. POOH w/ metal marks indicating along fishing neck side & 1 piece wire approx. 1' long. RIH w/3"to 6,459' WLM w/tool, would not latch. POOH. RIH w/single prong wire grab baited w/2.72" cent. w/2-1/2" JUC to 6,456' WLM w/tool to 6,459' WLM. POOH dragging weight, lost weight @ 5,700' w/tool to 5,762' WLM,tool came free. POOH, pin sheared. RIH w/2-1/2"JUC to 5,762' WLM. POOH, 1 piece wire 8". RIH w/3" GS to 5,762' WLM, latch w/tool came free. POOH, hung up 5,700'-5,630' w/tool came free. POOH w/upper packoff, 11' spacer pipe, 2 pieces wire, 1'total. Rubber element on packoff missing. RIH w/3" GS to 6,478' WLM, sit w/tool. POOH, no over pull, possible rubber element. RIH w/3 prong wire grab baited w/2-1/2"JUC to 6,480' WLM w/tool to 6,489' WLM. POOH w/2" piece of rubber element. RIH w/2.72" lib to 6,480' WLM, hit 2 times, POOH, impression of wire. RIH w/2.25" pump bailer to 6,494' WLM w/tool to 6,509' WLM. POOH, 1 cup sand. Metal marks on bottom. RIH w/single prong wire grab baited w/2.72" cent. w/2-1/2"JUC to 6,504' WLM w/tool to 6,554'WLM. POOH. RIH w/3" GS to 6,542' WLM, sit w/tool to 6,557'WLM, would not latch, no over pull. POOH, lay down lub, secure well for night and return to camp. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SLU 41-33RD Wireline 50-283-20055-01-00 209-010 12/22/15 6/17/16 Daily Operations: 06/16/2016-Thursday Safety meeting,JSA permit. Arrive on pad, cut wire, re-head, check tool string. RIH w/2.25" DD bailer to 6,498' WLM w/tool to 6,548' WLM w/tool would not pass. POOH, full sand. RIH w/same to 6,530' WLM w/tool to 6,553' WLM. POOH, full same. RIH w/same to 6,547' WLM w/tool to 6,558' WLM. POOH, full same. RIH w/same to 6,550' WLM w/ tool to 6,558' WLM. POOH, full same. RIH w/same to 6,530' WLM w/tool to 6,556' WLM. POOH, full soupy mud. RIH w/same to 6,550' WLM w/tool to 6,558' WLM. POOH, full same. RIH w/same to 6,555'WLM w/tool to 6,558' WLM. POOH, full 1/4 solids, 3/4 soupy mud. RIH w/same to 6,556' WLM w/tool to 6,559' WLM. POOH,full same. LD lub, check tool string, secure well for night. Arrive Hilcorp camp. 06/17/2016- Friday Safety meeting JSA permit.Arrive on pad p/u lub stab on riser. RIH w/2.25" DD bailer to 6,503' WLM w/tool to 6,517' WLM. POOH, full sand. RIH w/2.25" DD bailer to 6,515' WLM w/tool to 6,530' WLM. POOH,full sand. RIH w/2.25" DD bailer to 6,530' WLM w/tool fell to 6,544' WLM w/tool to 6,558' WLM. POOH, full same. RIH w/same to 6,555' WLM w/tool to 6,558' WLM. POOH, full same. RIH w/same to 6,558' WLM w/tool to 6,561' WLM. POOH, full same. POOH, lay down lub, clean area, secure well for production. 14 • ACTUAL SCH E MATO Wemp Lake U33 Well: SLU 4 Unit RD Completion Ran: 3/19/09 PTD: 209-010 API: 50-283-20055-01 CASING DETAIL Description Weight Grade Conn ID Length Top Btm TOC Rotate Hrs RKB GL=16.80' RKB too MSL=45.45.10' Structural 30" N/A N/A Weld NA 77' 0' 77' Driven 32.0 hrs Surface 20" 94.0# H-40 BTC 19.124" 424' 0' 424' Surf 77.5 hrs 1Intermediate 13-3/8" 72.0# N-80 BTC 12.347" 2,512' 0' 2,512' Surf 240.8 hrs Intermediate 9-5/8" 43.58 N-80 BTC 8.755" 2,884' 0' 2,884' Surf 560.5 hrs 30' Production 7-5/8" 29.78 L-80 BTC-Mod 6.875" 123' 0' 123' 180.0 hrs Production 7" 26.08 L-80 BTC-Mod 6.276" 5,997' 123' 6,120' 2,196' 180.0 hrs . f Liner 3-1/2" 9.2# L-80 IBT-Mod 2.992" 4,125' 5,003' 9,128' 5,003' 0.0 hrs '4' TUBING DETAIL Tubing 3-1/2" 9.2# L-80 TC-Il 2.992" 5,003' 0' 5,003' 20"- Heat String 1.660" 3.02# L-80 BTS-8 1.278" 2,986' 0' 2,986' 467'Bowl I JEWELRY DETAIL No Description Depth Length ID OD 13-3/8" 1 1 Tubing Hanger,Dual FTC-D-DFF6H,3-1/2"MCA,1.900"IJ Lift Threads 17.5' 0.97' - - 2 7"Baker ZXP packer(set 3/18/09) 5,003' 14.81' 5.250" 6.000" 9-5/8.'1413 7"x5"Baker Flex-Lock III liner hanger(set 3/18/09) 5,018' 7.30' 5.250" 5.910" — 4 Baker Model 80-40 Sealbore w/GBH-22 Seal Assembly 5,025' 8.45' 4.000" 5.000" 5 AD Stop 6,547' 2' 1.500" 2.992" 6 Slip-Stop,Macco Pack-off,Slip-Stop w/cement SI dump bailed(7/16/09) 8,426' - - - 7 Bridge Plug w/45'cement dump bailed(set 4/5/09) 9,033' 27.87' - - 8 PBTD-Top of 3-1/2"Float equipment(tag 3/25/09) 9,093' - - - PERFORATIONS .~ 2 -.-_ ID Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Gun Size SPF Phase Status Date Ili ' 3 A Beluga 6,567' 6,567.5' 5,944' 5,944.5' 0.5' 2.0" 4 6/29/2012 B Beluga 6,576' 6,586' 5,953' 5,963' 10' 2.0" 6 60 deg Isolated 6/29/2012 4 B Beluga 6,578' 6,578.5' 5,955' 5,955.5' 0.5' 2.0" 4 Isolated 6/29/2012 ( i C Beluga 7,502' 7,511' 6,879' 6,888' 9' 2.5" 6 60 deg 7/23/2009 10'Pup Joint D Tyonek 8,462.5' 8,494' 7,840' 7,871' 30' 2.5" 6 60 deg Isolated 6/21/2009 @ 5,937' 7-5/8"At' , E Tyonek 8,866' 8,880' 8,243' 8,257' 14' 2.5" 6 60 deg Isolated 5/27/2009 Note:Tagged Fill w/GS tool @ 6,561'WLM 06/17/2016 5 B - 10'Pup Joint Note:Tagged Fill 1.25"tools @ 7,110' KB on 11/13/2015 @6,718' CEMENT 10'Pup Joint Casing @ 7,652' Size Top Bottom ppg/sx Notes C 30" N/A N/A N/A No Cement 20" Surf. 424' N/A N/A 13-3/8" Surf. 2,512' N/A N/A 9-5/8" Surf. 2,884' N/A N/A II 7-5/8" 2,196' 6,120' 15.8ppg/412sx N/A ,,ra 6 7" 5,810' 8,950' 12.Sppg/450sx N/A 10'PupJoint ''r'' @ 8,406' Note:Tagged TOC @ 8,355'on 7/22/2009 D E 7 8 J I PBTD=9,093'MD/8,425'TVD 7 4` hTD=10,160'MD/9,492'TVD 6-118„ '' Max Deviation 49.5°@ 4,670' Open Hole Max Dogleg 5.7°/100'@ 3,585' Downhole Revised: 11/24/12 Updated by DMA 07-11-16 OF ID • V ,,w\��\��j,s� THE STATE Alaska Oil and Gas o Conservation Commission f LS]<.A _ _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFALAS"� Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson 9 n � Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Stump Lake Field, Undefined Gas Pool, SLU 41-33RD Sundry Number: 315-728 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster elay Chair DATED this of December, 2015 Encl. RBEIMSWfiu 17 20B RECEIVED • STATE OF ALASKA • ')EC 0 2 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION I .//ii/ 5 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations E. Fracture Stimulate ❑ Repair Well ❑✓ - Operations shutdown❑ Suspend ❑ Perforate E • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Remove Patch 0 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: eeid44.4 Hilcorp Alaska,LLC Exploratory ❑ Development E . 209-010 - 3.Address. Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 50-283-20055-01-00 ' 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055(a)(4) Stump Lake Unit(SLU)41-33RD . Will planned perforations require a spacing exception? Yes ❑ No ❑J • 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0058790 Stump Lake Unit/Undefined Gas - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,160 9,537 8,426 7,806 1,517 9,033' N/A Casing Length Size MD TVD Burst Collapse Structural 77' 30^ 77' 77' Conductor Surface 424' 20" 424' 424' 1,530 psi 520 psi Intermediate 2,512' 13-3/8" 2,512' 2,512' 5,380 psi 2,670 psi Intermediate 2,884' 9-5/8" 2,884' 2,884' 6,330 psi 3,810 psi Production 123' 7-5/8" 123' 123' 6,890 psi 4,790 psi Production 5,997' 7" 6,120' 5,506' 7,240 psi 5,410 psi Liner 4,125' 3-1/2" 9,128' 8,505' 10,160 psi 10,540 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: 3-1/2"LS Tubing Grade: L-80 Tubing MD(ft): 5,003' See Attached Schematic See Attached Schematic 1.660"HS L-80 2,986' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"Baker ZXP-N/A 5,003'MD;4,569'TVD-N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic f Development ❑✓ • Service ❑ 14. Estimated Date for 15.Well Status after proposed work: CommencingOperations: December 16,2015 OIL WINJ WDSPL P ❑ ❑ ❑ Suspended ❑ 16.Verbal Approval: Date: GAS E • WAG LI GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact_ Joe Kaiser-777-8393 Email jkaiser@hilcorp.com Printed Name Chad H/elgeesson Title Operations Manager Signature 1/,i ti�R Phone 907-777-8405 Date 1 Z/i/15— COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 315- -725s) Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RgDM�EC 17 2015 Post Initial Injection MIT Req'd? Yes LI No ❑ ■�"" Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: /0 — I 04/ U APPROVED BY / Approved by: /� / 7�^' COMMISSIONER THE COMMISSION Date: 2 7 f'p — /S SShmif Fnrm nnri Form 10-403 Re ised 11/2015 CrtioltptliNopt lid for 12 m the from the date of approval. Attachments in Duplicate • iii0 . , Well Prognosis Well: SLU 41-33RD Hilcorp Alaska,LL Date: 11/30/2015 Well Name: Stump Lake 41-33RD API Number: 50-283-20055-01 Current Status: SI Gas Well Leg: N/A Estimated Start Date: December 15th, 2015 Rig: Slickline/E-line Reg.Approval Req'd? N/A Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777- Permit to Drill Number: 209-010 8305 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907)952-8897 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Maximum Expected BHP: -2,280 psi @ 7,628' TVD (Static Survey 10-17-2009) Max. Predicted Surface Pressure: - 1,517 psi (Gas Gradient 0.1 psi/ft.) Brief Well Summary Well was drilled and initially perforated in May 2009. It initially flowed 1.2MMscfd at 1,550 psi FTP. Additional perfs were added in June 2012 from 6,576'to 6,586' with 2.0" perforating guns. The well immediately sanded - in and watered up the deeper producting zones. Multiple trips were made with slickline to bail sand. There have been pieces of coal, fine sand, course sand, etc., pulled from this well since perforating in 2012. In 2012, a , tubing patch was placed in the tubing to hold back water.The well is currently shut-in. Most recent tag is at 7,110'. Purpose of sundry is to add perforations in Beluga formation and reinstall the patch. Gly / 4.,a-a 6zB- ,„g../,:i.e 11-i-,-.- .0a-i..0,..4.---c•-.14-,-17 2C...2i Notes Regarding Wellbore Condition `L-Z..7;- �,n 0 • The well has not flowed since 2012. ' 1 L • Tubing patch in well causes restriction G s • Sticky sand tagged "'7,110 on 11/13/2015 rN1� Slickline Procedure: 1. MIRU Slickline PT lubricator to 2,500 psi Hi 250 Low with McOH/Water mix. • 2. PU w/ GR assembly, RIH to-6,572', POOH, LD GR assembly. • 3. PU w/tubing patch latch assembly, RIH, latch onto tubing patch, POOH, LD tubing Qatch..nd latch assembly, and redress seats on tubing patch. 4. PU w/2.5” bailer assembly, RIH, perform bailing operations down to 7,550', PO H, LD bailing g/41(- assembly. a. Contingency swabbing operations at direction of Engineer i. PU w/3.5" swab assembly and swab on well. Conclude swab operations by POOH and LD swab assembly. 5. PU 2.375" dummy gun, RIH to top of fill, POOH, LD GR. 6. RD Slickline E-Line Procedure: 7. Rig up E-line, PT lubricator to 2,500 psi Hi 250 Low with McOH/Water mix. 8. RU 2-3/8" 5 spf wireline guns. • ,. , • HWell Prognosis Well: SLU 41-33RD Hilcorp Alaska,LL Date: 11/30/2015 9. RIH and perforate the following intervals: Zone Sands Top(MD) Btm (MD) FT SPF Beluga BELUGA 6421 6426 5 5 Beluga SL 59-8 6535 6565 30 5 Beluga SL 61-3 6680 6687 7 5 PA4/..(e--/ Beluga SL 66-8 7229 7249 20 5 Beluga SL 67-6 7311 7317 6 5 Beluga SL 68-6 7378 7393 15 5 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Cement Bond Log (pending Tie-in log). d. Use Gamma/CCL/to correlate. e. Install Crystal gauges before perforating to monitor pressure. 10. RD E-line. 11. Turn well over to production. Slickline Procedure: 12. RU Slickline. PT lubricator to 2,500 psi Hi 250 Low with McOH/Water mix. 13. PU redressed tubing patch, RIH, set at^'6,572', POOH. 14. RD Slickline. E-line Procedure(Contingency): 15. If any zone produces sand and/or water. 16. MIRU E-line, PT lubricator to 2,500 psi Hi 250 Low with McOH/Water mix. 17. RIH and set 3-1/2" CIBP at depth above zone. Or 18. RIH and set 3-1/2"Tubing Patch across a zone. Attachments: 1. Actual Schematic 2. Proposed Schematic Stump Lake Unit S ACTUAL SCHEMA14 I�`, Well: SLU41-33RD ' dacorpAlaska,I,Lc Completion Ran: 3/19/09 PTD: 209-010 API: 50-283-20055-01 CASING DETAIL Description Weight Grade Conn ID Length Top Btm TOC Rotate Hrs RKB to GL=16.80' Structural 30" N/A N/A Weld NA 77' 0' 77' Driven 32.0 hrs RKB to MSL=45.10' Surface 20" 94.08 H-40 BTC 19.124" 424' 0' 424' Surf 77.5 hrs 1 30` Intermediate 13-3/8" 72.08 N-80 BTC 12.347" 2,512' 0' 2,512' Surf 240.8 hrs .1 Intermediate 9-5/8" 43.58 N-80 BTC 8.755" 2,884' 0' 2,884' Surf 560.5 hrs Production 7-5/8" 29.7# L-80 BTC-Mod 6.875" 123' 0' 123' - 180.0 hrs Production 7" 26.08 L-80 BTC-Mod 6.276" 5,997' 123' 6,120' 2,196' 180.0 hrs Liner 3-1/2" 9.28 L-80 IBT-Mod 2.992" 4,125' 5,003' 9,128' 5,003' 0.0 hrs TUBING DETAIL Tubing 34/2" 9.28 L-80 TC-II 2.992" 5,003' 0' 5,003' .*„ • r, Heat String 1.660" 3.02# L-80 BTS-8 1.278" 2,986' 0' 2,986' ` 467'Bowl - "` JEWELRY DETAIL . No Description Depth Length ID OD 13-3i8` 1 Tubing Hanger,Dual FTC-D-DFF6H,3-1/2"MCA,1.900"IJ Lift Threads 17.5' 0.97' - - 2 7"Baker ZXP packer(set 3/18/09) 5,003' 14.81' 5.250" 6.000" 20' _ 3 7"x5"Baker Flex-Lock III liner hanger(set 3/18/09) 5,018' 7.30' 5.250" 5.910" 4 Baker Model 80-40 Sealbore w/GBH-22 Seal Assembly 5,025' 8.45' 4.000" 5.000" 5 AO Stop,24'Patch(1.5"ID),D&D Packoff,AD Stop 6,572' 27' 1.500" 2.992" 6 Slip-Stop,Macco Pack-off,Slip-Stop w/cement SL dump bailed(7/16/09) 8,426' - - - 7 Bridge Plug w/45'cement dump bailed(set 4/5/09) 9,033' 27.87' - - • 8 PBTD-Top of 3-1/2"Float equipment(tag 3/25/09) 9,093' - - - PERFORATIONS w 2 },f,t, ID Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Gun Size SPF Phase Status Date .,] r t i.3 A Beluga 6,567' 6,567.5' 5,944' 5,944.5' 0.5' 2.0" 4 6/29/2012 B Beluga 6,576' 6,586' 5,953' 5,963' 10' 2.0" 6 60 deg Isolated 6/29/2012 4 B Beluga 6,578' 6,578.5' 5,955' 5,955.5' 0.5' 2.0" 4 Isolated 6/29/2012 C Beluga 7,502' 7,511' 6,879' 6,888' 9' 2.5" 6 60 deg 7/23/2009 • 10'Pup Joint 'a D Tyonek 8,462.5' 8,494' 7,840' 7,871' 30' 2.5" 6 60 deg Isolated 6/21/2009 ft 5, 5/893 S ,} E Tyonek 8,866' 8,880' 8,243' 8,257' 14' 2.5" 6 60 deg Isolated 5/27/2009 5 M B Pry 1108Pup ,i Note:Tagged Fill 1.25"tools @ 7,110' KB on 11/13/2015 I t. CEMENT 10'Pup Joint 4i It � Casing 0,7,652' ' r'G( Size Top Bottom ppg/sx Notes C 30" N/A N/A N/A No Cement rt ct 20" Surf. 424' N/A N/A .' , 13-3/8" Surf. 2,512' N/A N/A A?i: 9-5/8" Surf. 2,884' N/A N/A a7-5/8" 2,196' 6,120' 15.8ppg/412sx N/A t++ 1 - 7" 5,810' 8,950' 12.Sppg/450sx N/A 6 10'Pup Joint `' " a.. R 8,406' 5 Note:Tagged TOC @ 8,355'on 7/22/2009 i. v`i. D E 1", 7 I `'I 8 PBTD=9,093'MD/8,425'ND 7 ~ TD=10,160'MD/9,492'ND s-lie"Open Max Deviation 49.5°@ 4,670' Hole Max Dogleg 5.7°/100'@ 3,585' Downhole Revised: 11/24/12 Updated by JEK 11/15/15 II PRCIOSED SCHEMATIC • Stump Lake Unit Well: SLU 41-33RD Hilcorp Alaska,LLC Completion Ran: 3/19/09 PTD: 209-010 API: 50-283-20055-01 CASING DETAIL Description Weight Grade Conn ID Length Top Btm TOC Rotate Hrs RKB to GL=16.80' - RKB to MSL=45.10' Structural 30" N/A N/A Weld NA 77' 0' 77' Driven 32.0 hrs Surface 20" 94.08 H-40 BTC 19.124" 424' 0' 424' Surf 77.5 hrs -71., 1 Intermediate 13-3/8" _ 72.08 N-80 BTC 12.347" 2,512' 0' 2,512' Surf 240.8 hrs Intermediate 9-5/8" 43.58 N-80 BTC 8.755" 2,884' 0' 2,884' Surf 560.5 hrs 30° Production 7-5/8" 29.7# L-80 BTC-Mod 6.875" 123' 0' 123' - 180.0 hrs Production 7" 26.08 L-80 BTC-Mod 6.276" 5,997' 123' 6,120' 2,196' 180.0 hrs Liner 3-1/2" 9.2# L-80 IBT-Mod 2.992" 4,125' 5,003' 9,128' 5,003' 0.0 hrs ' TUBING DETAIL Tubing 3-1/2" 9.2# L-80 TC-II 2.992" 5,003' 0' 5,003' 467Bowl Heat String 1.660" 3.02# L-80 BTS-8 1.278" 2,986' 0' 2,986' ' JEWELRY DETAIL No Description Depth Length ID OD 9-5/8' • • 1 Tubing Hanger,Dual FTC-D-DFF6H,3-1/2"MCA,1.900"LI Lift Threads 17.5' 0.97' 2 7"Baker ZXP packer(set 3/18/09) 5,003' 14.81' 5.250" 6.000" , ^." 3 7"x5"Baker Flex-Lock III liner hanger(set 3/18/09) 5,018' 7.30' 5.250" . 5.910" " 4 Baker Model 80-40 Sealbore w/GBH-22 Seal Assembly 5,025' 8.45' 4.000" 5.000" 5 AD Stop,24'Patch(1.5"ID),D&D Packoff,AD Stop 6,572' 27' 1.500" 2.992" 6 Slip-Stop,Macco Pack-off,Slip-Stop w/cement SI dump bailed(7/16/09) 8,426' - - - 7 Bridge Plug w/45'cement dump bailed(set 4/5/09) 9,033' 27.87' -- - 8 PBTD-Top of 3-1/2"Float equipment(tag 3/25/09) 9,093' i PERFORATIONS I �u 2 Gun •„ ;i 3 ID Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Size SPF Phase Status Date -; G Beluga 6421 6426 5799 5804 5' 2.375" 5 . 60 Proposed " 4 G Beluga SL 59-8 6535 6565 5913 5942 30' 2.375" 5 60 Proposed -� A Beluga 6,567' 6,567.5' 5,944' 5,944.5' 0.5' 2.0" 4 6/29/2012 10'Pup Joint B Beluga 6,576' 6,586' 5,953' 5,963' 10' 2.0" 6 60 Isolated 6/29/2012 @ 5,937 B Beluga 6,578' 6,578.5' 5,955' 5,955.5' 0.5' 2.0" 4 Isolated 6/29/2012 7-5/9' i ;* JF Beluga SL 61-3 6680 6687 6057 6064 7' 2.375" 5 60 Proposed G F Beluga SL 66-8 7229 7249 6607 6627 20' 2.375" 5 60 Proposed A F Beluga SL 67-6 7311 7317 6688 6694 6' 2.375" 5 60 Proposed 5 B F Beluga SL 68-6 7378 7393 6710 6755 15' 2.375" 5 60 Proposed 10'Pup Joint C Beluga 7,502' 7,511' 6,879' 6,888' 9' 2.5 66 60 7/23/2009 @ 6,718' F D Tyonek 8,462.5' 8,494' 7,840' 7,871' 30' 2.5" 6 60 Isolated 6/21/2009 Iq E Tyonek 8,866' 8,880' 8,243' 8,257' 14' 2.5" 6 60 Isolated 5/27/2009 10'Pup Joint,''1" @ 7,652' r.. — cV Note:Tagged Fill 1.25"tools @ 7,105'on 11/24/2012 t I190 " CEMENT 4 . Casing • E Size Top Bottom ppg/sx Notes T " 5 30" N/A N/A N/A No Cement 10'Pup Joint -,'`i' 20" Surf. 424' N/A N/A @ 8,406' 13-3/8" Surf. 2,512' N/A N/A 9-5/8" Surf. 2,884' N/A N/A 7-5/8" 2,196' 6,120' 15.8ppg/412sx N/A D 7" 5,810' 8,950' 12.Sppg/450sx N/A E Note:Tagged TOC @ 8,355'on 7/22/2009 7 7„ PBTD=9,093'MD/8,425'ND TD=10,160'MD/9,492'ND 6-1/8"Open Max Deviation 49.5°@ 4,670' Hole Max Dogleg 5.7'/100'@ 3,585' Downhole Revised: 11/24/12 Updated by JEK 11-30-2015 Oth Nolan Hilcorp Alaska, GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 Ilihurp Vaskn.i.i. . Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 12/03/15 To: Alaska Oil & Gas Conservation Commission Makana Bender ! ,F,. y Natural Resource Technician II I'"C C ! �,t` r 333 W 7th Ave Ste 100 Anchorage, AK LEL 04 LEI:: 99501 AOG CC DATA TRANSMITTAL SLU 44-33RD _5- V/- .33re2 Elog and Mudlog digital data _ CD1: Elog digital data SW 41-33 TLGS data 215120091:26 PM LAS File 6 KB T17835_mudlog 4/8/200910:51 AM LAS File 4,877 KB T17867_main_SLT_CNL 008LUP_resend 4/8/2009 9:15 AM LAS File 2,191 KB T17867 repeat_SLT_CNL 010LUP 4/8/2009 9:12 AM LAS File 201 KB T17910_Iwd_depth_shift_04-20-2009 3/16/2011 10:13 AM LAS File 4,639 KB SCANNED AUG 1 02016 Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: 0 0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. coq - 0 LC) Well History File Identifier Organizing (done) ❑ Two -sided III IIIIIIIIIII IIIII ❑ Rescan Needed III 1 11111 RE CAN DIGITAL DATA OVERSIZED (Scannable) olor Items: ❑ Diskettes, No. ❑Maps: Greyscale Items ❑Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: .5 1 " / / /s/ vYIP Project Proofing 111 IIIIJIHIII Date: 5 1 /s/ f Scanning Preparation J x 30 = 1(..57) + p`,3 = TOTAL PAGES / '73 BY: digl. Date: J 9 (Count does not include cover sheet) ' u '/ /s/ f Production Scanning III 1111111 IIIII Stage 1 Page Count from Scanned File: / P7 L i (Count does include cover eet) Page Count Matches Number in Scann'ng Preparation: YES NO BY: Dater 9 ► , ! p l i /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO f BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 1311111 1111 ReScanned 11111111H 1111 BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII1IIIIllI 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA AL& OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Lf Repair Well U Plug Perforations U Perforate U Other U Coil Tubing Cleanout Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development CI Exploratory ❑ 209 -010 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99504 50- 283 - 20055 -01 �- CO 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0058790 Stump Lake Unit (SLU) 41 -33RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Stump Lake Unit / Undefined Gas 11. Present Well Condition Summary: Total Depth measured 10,160 feet Plugs measured 9,033 feet true vertical 9,537 feet Junk measured N/A feet Effective Depth measured 9,093 feet Packer measured 5,003 feet true vertical 8,470 feet true vertical 4,586 feet Casing Length Size MD TVD Burst Collapse Structural 77' 30" 77' 77' Conductor Surface 424' 20" 424' 424' 1,530 psi '" 1 " 01111 . 1" 520 psi Intermediate 2,512' 13 -3/8" 2,512' 2,512' 5,380 psi 2,670 psi Intermediate 2,884' 9 -5/8" 2,884' 2,884' 6,330 psi 3,810 psi Production 123 7 -5/8" 123 123' 6,890 psi 4,790 psi Production 5,997' 7" 6,120' 5,506' 7,240 psi 5,410 psi Liner 4,125' 3 -1/2" 9,128' 8,505' 10,160 s 10,540 psi r1 Q AN 2 8 2 Perforation depth Measured depth See Attached Schematic iCANNE True Vertical depth See Attached Schematic 3 -1/2" LS L -80 5,003' MD 4,586' TVD Tubing (size, grade, measured and true vertical depth) 1.660" HS L -80 2,986' MD 2,986' TVD 5,003' MD Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP 4,586' TVD N/A N/A fi -,, ,.,.', , 12. Stimulation or cement squeeze summary: N/A p ;Wa Intervals treated (measured): N/A �; r . { Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Inject o et g' L- ' wag Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 116 Subsequent to operation: 0 0 0 0 138 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development 0 ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ . Gas 0 WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -366 Contact Chad Helgeson Email chelgesonC5 hilcoro.com Printed Name Chad Helgeson Title Operations Engineer Signature ' 74‘11111111 hone 907 - 777 -8405 Date 10/26/2012 corm 1U -4U4 Keviseo 1umut ' 1- ,ii I 4 9 - Wk 1 uon orl lnal only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SLU 41 -33RD 50- 28320 - 055 -00 176 -086 9/26/12 9/28/12 Daily Qperatiohs: 09/26/2012 - Wednesday Finish rig up. Mr. Regg with AOGCC waived witness to BOP test. Test BOP to 250 psi low and 2,500 psi high. RIH with 1 -1/2" coil, dual check valves, 4' stinger and jet nozzle to 200'. Break circulation and pump .3 bpm. Check up wt every 1000'. Circ pressure 289 psi and started getting a little sand back at 2,650'. At 5,257' coil set down on a bridge. Increase rate to 1 bpm, circ press 2,300 psi. Cleaned out thru the perf zone from 6,567' down to 6,800'. Picked back up and worked coil slowly from 6,560' to 6,530' several times. Rigged coil for standby and secured well for night. 09/27/2012 - Thursday Shell test BOP to 250 psi low and 2,500 psi high. Clean sand out of choke. Well had 7 psi on tubing. RIH with coil, circulating .25 bpm, circ pressure 200, WH pressure 3 psi down to 6,500'. Getting little sand back. RIH to 6,545' and hit bridge at 6,953', 7,430', 8,074', and 8,254'. Tag hard at 8,323'. Could not go any deeper. Slickline tag TOC at 8,355' on 7/22/09. Mixed and pumped a 50 bbl Gel sweep around and got back small to medium amount of sand. Started back out of hole with same rate after sweep with no problems to 4,000'. Started N2 and lifted fluid out of hole at 600 scfm from 4,000' to surface with 600 psi back pressure. Shut well in with 700 psi on well. Rigged down injector and BOP off well. Put bowen connection back on well. Turned well over to production. 09/28/2012 - Friday RD equipment, move to barge landing. • y of T$ �*� „ THE STATE Alaska Oil and Gas °fALA Commission S� C onservation Ci GOVERNOR SEAN PARNELL 333 West Seventh Avenue AL AS - .0 Anchorage, Alaska 99501 -3572 G °( Main: 907.279.1433 A Fax: 907.276.7542 Chad Helgeson Operations Engineer ca oq. 0 ! a Hilcorp Alaska, LLC J 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Stump Lake Field, Undefined Gas Pool, Stump Lake Unit 41 -33RD Sundry Number: 312 -366 Dear Mr. Helgeson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4 :30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this Z _ tray of October, 2012. Encl. • • ti • o la r STATE OF ALASKA P S E P 2 6 4 .4 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Cal Tubing Clean Out 151 • 2. Operator Name: 4. Current Well Cla--+ 5. Permit to Drill Number. Hilcorp Alaska, LLC Development U .l '1,' 0 / ❑ 209 -010 • 3. Address: Stratigraphic ❑ / L Service ❑ 6. API Number. 3800 Centerpoint Drive, Suite 100, Anchorage, AK 99503 50 -283- 20055-01 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number line where ownership or landownership clan property P P es: 9 Spacing Exception Required? Yes ❑ No El Stump Lake Unit (SLU) 41-33RD 9. Property Designation (Lease Number): 10. Field / Pool(s): Stump Lake Unit (ADL0058790) Stump Lake Unit / Undefined Gas . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,160 9,537 8,426 7,806 N/A N/A Casing Length Size MD TVD Burst Collapse Structural 77' 30" 77' 77' Conductor 424' 20" 424' 424' 1,530 psi 520 psi Surface 2,512' 13 -3/8" 2,512' 2,512' 5,380 psi 2,670 psi Intermediate 2,884' 9 -5/8" 2,884' 2,884' 6,330 psi 3,810 psi I Production 6,120' 7 -5/8" x 7" 6,120' 5,506' 6,890 psi 4,790 psi Liner 4,125' 3 -1/2" 9,128' 8,505' 10,160 psi 10,530 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 3 -1/2" LS Tubing Grade: L -80 Tubing MD (ft): 5,003' See Attached Schematic See Attached Schematic 1.660" HS L -80 2,986' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 7" Baker ZXP - N/A 5,003' MD; 4,569' TVD - N/A 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/26/2012 Oil ❑ Gas IS • WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson 777 -8405 Printed Name ( Chad Helgeson Title Operations Engineer Signature Phone Date 9/26/2012 777 -8405 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 12.- ✓( Plug Integrity ❑ BOP Test �� Mechanical Integrity Test ❑ Location Clearance ❑ Other: 6 /'' -f t-5 f 3 Uaa P5 l Al / 4-0 at C /-o f SS 1-c 51- . Subsequent Form Required: / t'2-40 - /.. APPROVED BY Approved by: ./ ..._ COMMISSIONER THE MMISSION Date: l 0 . 2 ) Z-.._ _ p U�� OCT 0 01 � ,v /� Form 10-403 Revised 1/2010 1 Z 0) 1 i' 0R1G1 Submit in Duplicate la l v i • • Well Prognosis Well: SLU 41 -33 Hilcorp Alaska, LLC Date: 9/25/2012 Well Name: Stump Lake 41 -33 API Number: 50- 283 - 20055 -01 Current Status: SI gas Well Leg: N/A Estimated Start Date: September 26, 2012 Rig: SLB CT #2 Reg. Approval Req'd? N/A Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 209 -010 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Luke Saugier (907) 777 -8395 (0) AFE Number: 1222012 Current Bottom Hole Pressure: — 2,214 psi @ 7,762' TVD (mid perf of 6,567' MD) Maximum Expected BHP: — 2,850 psi @ 7,628' TVD (New perfs being added) Max. Allowable Surface Pressure: 2500 psi (Using 0.435psi /ft to surface) 2 Brief Well Summary Well was perforated in June 2012 from 6,576' to 6,586' with 2.0" perforating guns. The well immediately sanded in. Multiple trips were made with slickline to bail sand, but fill was last tagged at 4,600ft. There have been pieces of coal, fine sand, course sand, etc, pulled from this well after perforating. Multiple bridges were seen on last slickline work at 1,450', 2,000', 4,400', 4,500' and 4,600'. Notes Regarding Wellbore Condition • Prior to perforating the well was making 600mcfd with about 100 psi tubing pressure. The well has not / flowed since the perforations were made June 29 Brief completion procedure: Csg. Size: 7 -5/8 Wt: 29.7 # 0' to 123', 7" 26.0# 123' to 6120' Liner Size: 3 -1/2" Wt.9.2 # ID 2.992" 3 -1/2" Liner 5003' to 9,128' to cmt then bridge plug. TBG 3 -1/2 o.d. 9.2 # w/ 2.992" ID 0' to 5003' Smallest ID: 2.992, Drift; 2.867" EOT: 9033' PBTD. Fill Depth: 4,600' Type of Fill: Coal, Formation Sand (fine beluga sand and course Tyonek sand) PBTD: 8,426' Perforations: 6,567' to 7,511' w/ 8,462' to 8,527' isolated Potential Problems: Influx of fill can overtake the work string, Wash slowly and keep the hole full. If string becomes sticky or gain significant pull wt. increase pump rate, Pulling up until normal wt returns. Watch for loss of returns and possible N2 use. 1. Safety Meeting, 2. MIRU 1.5" CTU W/ Associated Equipment, Perform visual on Equipment for standard operational safety and performance ability . 3. MU BHA #1: Roll on Type internal Wash -Tip, Keeping OD @ 1.5 4. NU Injection Head to WH • • Well Prognosis Well: SLU 41 -33 Hilcorp Alaska, LLC Date: 9/25/2012 5. Test Surface Iron 500psi low x 2,500 psi High 6. RIH 50 -75 FPM filling hole and getting good circulation, use PW w/ gel added, pump Y2 BPM. 7. After obtaining good circulation Raise rate to 1.0 BPM , staying @ 50 -75 FPM. If Circulation becomes an issue a. Pump 500 N2 and %2 BPM fluid b. Pull -Up hole c. regain circ. d. continue in hole. 8. From 4,000' run a gel sweep every 500'. And pull up for wt check. After washing begins, wash only 50', picking up 50' 9. Once bridges are washed out there is possible cross flow from the new perfs at 6,586 to perfs at 7,511. Circulate sweeps at 6586 and ensure hole is clean before circulating deeper than 6,586. 10. Wash to PBTD (8,426') Circulating 2 sweeps from bottom . 11. Unload water with N2 from 4,000ft to surface, maintaining a back pressure on the well. 12. POOH 13. RDMO CTU and associated Equipment Note: If a wash tip encounters fill that is too hard to wash, Engineer (Chad Helgeson) will be notified and discuss 1 -11/16 motor w/ 2.75 mill or bit from Olgoonik with Pat Grant. Attachments: 1. Schematic la • • Stump Lake Unit SCHEMATIC Well: SLU4133RD ' HilcorpAlaeka,L As Completed: TBD Casing & Tubing RKB to GL = 16.80' Description Weight Grade Conn ID Length Top Btm TOC Rotate Hrs RKB to MSL = 45.10' Structural 30" N/A N/A Weld NA 77' 0' 77' Driven 32.0 hrs 3 1 Surface 20" 94.0# H -40 BTC 19.124" 424' 0' 424' Surf 77.5 hrs Intermediate 13 -3/8 72.08 N -80 BTC 12.347" 2,512' 0' 2,512' Surf 240.8 hrs Intermediate 9 -5/8" 43.58 N -80 BTC 8.755" 2,884' 0' 2,884' Surf 560.5 hrs 30" Production 7-5/8" 29.78 L -80 BTC -Mod 6.875" 123' 0' 123' 180.0 hrs Production 7" 26.08 L -80 BTC -Mod 6.276" 5,997' 123' 6,120' 2,196' 180.0 hrs 0 Liner 3 -1/2" 9.28 L -80 IBT -Mod 2.992" 4,125' 5,003' 9,128' 5,003' 0.0 hrs 20"...A ■ Tubing 3 -1/2" 9.28 L -80 TC -II 2.992" 5,003' 0' 5,003' 467' Bowl Heat string 1.660" 3.028 L -80 BTS -8 1.278" 2,986' 0' 2,986' Jewelry & Fish No Description Depth Length ID OD 13 -3/6" -4 L 1 Tubing Hanger, Dual FTC- D- DFF6H, 3 -1/2" MCA, 1.900" IJ Lift Threads 17.5' 0.97' - - 2 7" Baker ZXP packer (set 3/18/09) 5,003' 14.81' 5.250" 6.000" 9-5/8' 3 7 "x5" Baker Flex-Lock III liner hanger (set 3/18/09) 5,018' 7.30' 5.250" 5.910" 4 Baker Model 80 -40 Sealbore w/ GBH -22 Seal Assembly 5,025' 8.45' 4.000" 5.000" 5 Slip -Stop, Macco Pack -off, Slip -Stop w/ cement SL dump bailed(7 /16/09) 8,426' - - - 6 Bridge Plug w /45' cement dump bailed (set 4/5/09) 9,033' 27.87' - - 7 PBTD - Top of 3 -1/2" Float equipment (tag 3/25/09) 9,093' - - - Perforations I.D. Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Gun Size SPF Phase Status Date iiiii 2 e; A Beluga 6,567' 6,567' 5,944' 5,944.5' 2 2.0" 6/29/2012 s 3 A Beluga 6,576' 6,586' 5,953' 5,963' 10' 2.0" 6 60 deg 6/29/2012 A Beluga 6,578' 6,578.5' 5,955' 5,955.5' 2 2.0" 6/29/2012 4 B Beluga 7,502' 7,511' 6,879' 6,888' 9' 2.5" 6 60 deg 7/23/2009 C Tyonek 8,462.5' 8,494' 7,840' 7,871' 30' 2.5" 6 60 deg Isolated 6/21/2009 10' Pup Joint C Tyonek 8,866' 8,880' 8,243' 8,257' 14' _ 2.5" 6 60 deg Isolated 5/27/2009 @ 5,937' 7 -5/8" Cement 10' Pup Joint Casing Size Top Bottom ppg/ sx Notes @ 6,718' 30" N/A N/A N/A No Cement 20" Surf. 424' N/A N/A I 13 -3/8" Surf. 2,512' N/A N/A 9 - 5/8" Surf. 2,884' N/A N/A 1. 7 -5/8" 2,196' 6,120' 15.8ppg/412sx N/A 7" 5,810' 8,950' 12.Sppg/ 450sx N/A up Joint @ 10' 7,P652' !' I B 5 10' Pup Joint @ 8,406' C ?6 7 I, 7" 4 bk 6 -1/8" Open Hole Total Depth= 10,160' PBTD = 9,033' Revised 8/8/2012 by TDF • • Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Friday, September 28, 2012 11:06 AM To: 'Chad Helgeson' Cc: Schwartz, Guy L (DOA) Subject: SLU 41- 33RD(PTD 209 -010, Sundry 312 -366) Chad, You have verbal approval to proceed with this CTU cleanout. Please note that the BOPs must be tested to 3000 psi and the AOGCC must be notified in advance of the BOP test. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson a(�alaska.gov i 1 • • • Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Friday, September 28, 2012 11:06 AM To: 'Chad Helgeson' Cc: Schwartz, Guy L (DOA) Subject: SLU 41- 33RD(PTD 209 -010, Sundry 312 -366) Chad, You have verbal approval to proceed with this CTU cleanout. Please note that the BOPs must be tested to 3000 psi and the AOGCC must be notified in advance of the BOP test. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson a(�.alaska.gov i 1 STATE OF ALASKA RECEIVER, ' ALASKA OIL AND GAS CONSERVATION COMMISSION AUG O 9 2Q12 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Repair Well (J Plug Perforations Li Perforate Other �, Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac 0 Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: ` Name: Hilcorp Alaska, LLC Development El Exploratory ❑ -' 209 -010 3. Address: 3800 Centerpoint Drive, Suite 100, Anchorage, Stratigraphic Service ❑ 6. API Number: Alaska 99503 50- 283 - 20055 -01 — 7. Property Designation (Lease Number): 8. Well Name and Number: Stump Lake Unit (ADL0058790) Stump Lake Unit (SLU) 41 -33RD '- 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): . Stump Lake Unit / Undefined Gas 11. Present Well Condition Summary: Total Depth measured 10,160 " feet Plugs measured N/A feet true vertical 9,537 . feet Junk measured N/A feet Effective Depth measured 9,093 feet Packer measured 5,003 feet true vertical 8,470 feet true vertical 4,569 feet Casing Length Size MD TVD Burst Collapse Structural 77' 30" 77' 77' Conductor 424' 20" 424' 424' 1,530 psi 520 psi Surface 2,512' 13 -3/8" 2,512' 2,512' 5,380 psi 2,670 psi Intermediate 2,884' 9 -5/8" 2,884' 2,884' 6,330 psi 3,810 psi Production 6,120' 7 -5/8" x 7" 6,120' 5,506' 6,890 psi 4,790 psi Liner 4,125' 3 -1/2" 9,128' 8,505' 10,160 psi 10,530 psi Perforation depth Measured depth see attached schematic True Vertical depth see attached schematic 3 -1/2" LS L -80 5,003' 4,569' Tubing (size, grade, measured and true vertical depth) 1.660" HS L -80 2,986' 2,986' 5,003' Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP 4,569' TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N /A AU 1 7 2Ul2 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 627 0 0 94 Subsequent to operation: 0 0 0 U 4 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development © – _ Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas 0 WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Chad Helgeson Phone: 777 -8405 Printed Name Chad Helgeson Title Operations Engineer Signature (�� . Phone 777 -8405 Date 8/7/2012 m 'V RBDMS AUG 0 9 d '' ( , q' z `�' Form 10 -404 Revised 11/2011 4 " ( 3 ` ' z__ Submit Original Only -+1 • 11 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SLU 41 -33RD Add Perfs 50- 283 - 20055 -01 209 -010 6/29/12 7/8/12 Dairy Operations: 06/29/2012 - Friday Mobe from Ivan River. 06/30/2012 - Saturday RU lubricator and pressure test to 2,500 psi. RIH with 2" x 15' spent dummy gun. Tie into CBL. GR /CCL dated 04- Apr -2009. 07/01/2012 - Sunday Nothing to report. 07/02/2012 - Monday Nothing to report. 07/03/2012 - Tuesday RU pressure test lubricator to 2,500 psi. RIH w/ 2.75" blind box to 1,102' wlm. POOH. RIH w/ 1.75" DD bailer to 2,590' wlm. POOH. RIH with 1.75 DD bailer to 2,560' wlm. POOH. Laid down, clean up area. Secure well for the night. 07/04/2012 - Wednesday RU, pressure test lubricator. Made 1 run with 2.5" bailer, worked to 1,425', changed bailer to 1.75 for 2 runs, worked to 2,705'. Changed back to 2.5" bailer, worked to 2,739', changed back to 1.75" bailer, worked to 2,780'. Made another run 2.5" bailer, worked to 2,780', changed back to 1.75" bailer, worked to 5,213'. Changed back to 2.5" bailer, worked to 5,211', made 2 more runs, 1 with 1.75 ", 1 with 2.5" bailer down to 5,226'. 07/05/2012 - Thursday PT wireline valve and lubricator to 2,500 psi. Made 1 run with 1.75" bailer down to 2,534', 1 run with 2.5" bailer. Worked to 5,185'. Units PTO not working, crew spent the rest of the day getting unit fixed, had to fly a mechanic over for repair. 07/06/2012 - Friday PT lubricator and RU. Made runs with 2.5" and 1.75 ", worked to 5,177', switching back between the 2.5" bailer and the 1.75" bailer, made it down to 5,260'. 07/07/2012 - Saturday RU and PT lubricator to 2,500 psi. Made 2 runs with 2.5" bailer, worked to 5,245', switched to 1.75" bailer down to 5,263'. Had some star bits, prongs sent out and started running those to break up the hard spots and then switching back between the 2.5" and 1.75" bailers, they made it down 5,266'. 07/08/2012 - Sunday RU and PT lubricator. Made 2 runs with the 2.5" bailer to get back down to 5,265', decision was made to blown down the tubing to 0 psi and then have wireline run back in and see what changed, after tubing pressure was at 0 psi, made a run with a 1.75" bailer down to 5,266', then ran a 19" X 3/4" prong and followed that with a 1.75" bailer down to 5,266', after not making hole it was decided shut down. Stump Lake Unit .,n W ell: SLU 41 -33RD Hilmr Alaska, W: P SCHEMATIC As Completed. TBD Casing & Tubing g RKB to GL = 16.80' Description Weight Grade Conn ID Length Top Btm TOC Rotate Hrs L RKB to MSL = 45.10' Structural 30" N/A N/A Weld NA 77' 0' 77' Driven 32.0 hrs r . 1 Surface 20" 94.0# H-40 BTC 19.124" 424' 0' 424' Surf 77.5 hrs Intermediate 13 -3/8" 72.0# N -80 BTC 12.347" 2,512' 0' 2,512' Surf 240.8 hrs Intermediate 9 -5/8" 43.5# N -80 BTC 8.755" 2,884' 0' 2,884' Surf 560.5 hrs 30 AI Production 7 -5/8" 29.7# L -80 BTC -Mod 6.875" 123' 0' 123' - 180.0 hrs Production 7" 26.0# L -80 BTC -Mod 6.276" 5,997' 123' 6,120' 2,196' 180.0 hrs Liner 3 -1/2" 9.2# L -80 IBT -Mod 2.992" 4,125' 5,003' 9,128' 5,003' 0.0 hrs 20 .8 Tubing 3 - 1/2" 9.2# L -80 TC -II 2.992" 5,003' 0' 5,003 ,,ry y 467 Bowl Heat string 1.660" 3.02# L -80 BTS -8 1.278" 2,986' 0' 2,986' ,,`r� , . • , , Jewelry & Fish No Description Depth Length ID OD 3 - 318" - - 1 Tubing Hanger, Dual FTC- D- DFF6H, 3 -1/2" MCA, 1.900" li Lift Threads 17.5' 0.97' - - 2 7" Baker ZXP packer (set 3/18/09) 5,003' 14.81' 5.250" 6.000" 9 3 7 "x5" Baker Flex-Lock 111 liner hanger (set 3/18/09) 5,018' 7.30' 5.250" 5.910" 4 Baker Model 80 -40 Sealbore w/ GBH -22 Seal Assembly 5,025' 8.45' 4.000" 5.000" 5 Slip -Stop, Macco Pack -off, Slip -Stop w/ cement SL dump bailed(7 /16/09) 8,426' - - - 6 Bridge Plug w/ 45' cement dump bailed (set 4/5/09) 9,033' 27.87' - - 7 PBTD - Top of 3 -1/2" Float equipment (tag 3/25/09) 9,093' - - - Perforations s I.D. Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Gun Size SPF Phase Status Date a , * , ; A Beluga 6,576' 6,586' 5,953' 5,963' 10' 2.0 6 60 deg 6/29/2012 ,1 ` 3 B Beluga 7,502' 7,511' 6,879' 6,888' 9' 2.5" 6 60 deg 7/23/2009 i r= C Tyonek 8,462.5' 8,494' 7,840' 7,871' 30' 2.5" 6 60 deg Isolated 6/21/2009 4 C Tyonek 8,866' 8,880' 8,243' 8,257' 14' 2.5" 6 60 deg Isolated 5/27/2009 10' Pup Joint Cement @ 5,937' x' 7 - 5/8 , j i Casing Size Top Bottom ppg/ sx Notes ' 30" N/A N/A N/A No Cement 20" Surf. 424' N/A N/A 10' Pup Joint 13 -3/8" Surf. 2,512' N/A N/A @ 6,718' ii 9 -5/8" Surf. 2,884' N/A N/A sfi 7 -5/8" 2,196' 6,120' 15.8ppg/412sx N/A 7" 5,810' 8,950' 12.5ppg/ 450sx N/A ttil 10' Pup Joint , ^ - I @ 7,652' . B i 5 10' Pup Joint R �►. @ 8406 ; ' 0) :. C il'3G C 1 6 7 7" 6 -1/8" Open Hole Total Depth= 10,160' PBTD= 9,033' Revised 8/8/2012 by TDF DATA SUBMITTAL COMPLIANCE REPORT 4/26/2011 Permit to Drill 2090100 Well Name /No. STUMP LK UNIT 41 -33RD Operator UNION OIL CO OF CALIFORNIA API No. 50- 283 - 20055 -01 -00 MD 10160 TVD 9537 Completion Date 7/23/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N REQUIRED INFORMATION e...--/ Log No Samples No Directional Survey Yes ` DATA INFORMATION Types Electric or Other Logs Run: ext to long for this data field. See 10-407 (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / • T .e Med /Frmt Number Name Scale Media No Start Stop CH Received Comments Rpt Report: Final Well R Open 4/10/2009 Final Well Report, Tab of Cont, Equip and Crew, Well Details, Geo Data, / Drill Data, Daily Reps ED C 17835 t eport: Final Well R Open 4/10/2009 Final Well Report, Tab of Cont, Equip and Crew, Well Details, Geo Data, Drill Data, Daily Reps w /Mud logs in PDS graphics wog Mud Log 2 Col 2900 10160 Open 4/10/2009 MD Formation Log ...tog Mud Log 2 Col 2900 10160 Open 4/10/2009 TVD Formation Log jog Mud Log 2 Col 2900 10160 Open 4/10/2009 MD LWD Combo Log f -t_"og Mud Log 2 Col 2900 10160 Open 4/10/2009 TVD LWD Combo Log og Mud Log 2 Col 2900 10160 Open 4/10/2009 MD Drilling Dynamics :.,,g Mud Log 2 Col 2900 10160 Open 4/10/2009 TVD Drilling Dynamics • og Induction /Resistivity 2 Blu 2855 10160 Open 4/20/2009 MD Vision Service 12 -Mar- 2009 Log Induction /Resistivity 2 Blu 2855 10160 Open 4/20/2009 TVD Vision Service 12 -Mar- 2009 C 17866 r �duction /Resistivity 2836 10157 Open 4/20/2009 EWR logs in PDS, CGM and EMF graphics Log Cement Evaluation 5 Col 5000 9045 Case 4/20/2009 CBL, ABC =Delta T, GR, CCL 4- Apr -2009 ` ED C Pds 17867. Evaluation 5000 9045 Case 4/20/2009 CBL, ABC =Delta T, GR, CCL 4- Apr -2009 C Las 17911duction /Resistivity 2836 10157 Open 4/23/2009 Depth Shift, DRBN, GR, ROP, RPM DATA SUBMITTAL COMPLIANCE REPORT 4/26/2011 Permit to Drill 2090100 Well Name/No. STUMP LK UNIT 41-33RD Operator UNION OIL CO OF CALIFORNIA API No. 5O-283-20055-01-00 MD 10160 TVD 9537 Completion Date 7/23/2009 Completion Status 1-GAS Current Status 1-GAS UIC N 94 [ . Gamma Ray 2 Col 4950 9150 Open 4/23/2009 LWD GR, Depth Shift QC Plot 12-Mar-2009 Perforation 2 Btu 7502 7511 Case 10/26/2009 Pert Rec GUN, CCL 23-Jul- 2009 ED C Pds 18784 4- Perforation 7502 7511 Case 10/26/2009 Perf Rec GUN, CCL 23-Jul- 2009 Well Cores/Samples Information: Sample Interval Set 4 111 Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y )1■LD Daily History Received? N Chips Received? 'Y / N Formation Tops ki N Analysis Received? Comments: a Compliance Reviewed By: —, Date: ,,, t-c.. 4 02-4314 _ , • • STATE OF 0 f o LIDS/tow ALASKA OIL AND GAS CONSE CONSERVATION ON COMMISSION RECEIVED � J WELL COMPLETION OR RECOMPLETION REPORT ANR la. Well Status: Oil ❑ Gas 0 SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Class: Abi 20AAC 25.105 20AAC 25.110 De ar OM Gas CI 41 i • ". fc n GINJ II WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ A p • Test • 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Num er: Union Oil Company of California Aband.: 7/23/2009 209 -010 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, Alaska, 99519 2/22/2009 50- 283 - 20055 -01 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 772' FNL, 505' FEL, Sec 33, T14N, R8W, SM 3/12/2009 Stump Lake Unit (SLU) 41 -33RD Top of Productive Horizon: 8. KB (ft above MSL): 45.1 15. Field /Pool(s): 563' FSL, 1647' FEL, Sec 28, T14N, R8W, SM GL Ground (ft MSL): 28.3 Stump Lake Unit Total Depth: 9. Plug Back Depth(MD +TVD): 550' FSL, 1637' FEL, Sec 28, T14N, R8W, SM 8,355' MD (7,732' TVD) Undefined Gas 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 375758 y- 2655295 Zone- 4 10,160' MD (9,537' TVD) ADL- 058790 [Stump Lake Unit] TPI: x- 374631 y- 2656642 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 374638 y- 2656629 Zone- 4 N/A N/A 18. Directional Survey: Yes El No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re- drill /Lateral Top Window MD/TVD: LWD[8- 1 /2 "GR- Res,6- 1 /8 "GR- Res - Den - Neu];Open Hole[GR -Res, Den,Neu,Son];Cased Hole [GR,Son,CBL] 2,867'MD (2,866'TVD) 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 30 129 X -56 0 77' 0 77' Driven N/A 0 20 68 L -80 0 424' 0 424' 26" 152 / 68 bbl (540 / 240 sx) 0 13 -3/8 40 L -80 0 2,512' 0 2,512' 17 -1/2" 563 / 14 bbl (2000 / 50 sx) 0 9 -5/8 26 L -80 0 2,884' 0 2,884' 12 -1/4" 93 bbl (330 sx) 0 7 -5/8/7 29.7/26 L -80 0 6,120' 0 5,506' 8 -1/2" 95 bbl (412 sx) 0 3 -1/2 9.2 L -80 5,003' 9,128' 4585 8,505' 6 -1/8" 152 bbl (450 sx) 0 24. Open to production or injection? Yes 0 Non If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 2.5" guns 6spf 7,502'- 7,511' (6,879' - 6,888' TVD) 3 -1/2" 5,003' 5,003' 1.660" (Heater String) 2,986' N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 7/25/2009 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 8/19/2009 24 Test Period 0 1,206 0 0 0 Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 1,550psi Opsi 24 -Hour Rate — 0 1,206 0 N/A 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Ei Sidewall Cores Acquired? Yes ❑ No El If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. RBDMS FEB 0 5 in . Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top N/A N/A needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base N/A N/A Depth (MD) Formation Test Results 8,866- 8,880' Tyonek 81 -8 No flow 8,462' - 8,493' Tyonek 77 -9 No flow 7,502'- 7,511' Beluga 69 -4 Flow well at 1.2MMCF /D / Beluga Coal 6,001' 5,393' Lower Sterling 6,072' 5,460' Sterling 56 -2 6,138' 5,523' Beluga Top 6,379' 5,757' Beluga 60 -7 6,607' 5,984' Beluga 67 -6 7,310' 6,687' Beluga 69 -4 7,502' 6,879' Tyonek 77 -9 8,462' 7,839' Tyonek 81 -8 8,866' 8,243' Formation at total depth: Tyonek 10,160 9,537 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola 263 -7640 Printed Na p . Timothy C. Brandenburg Title: Drilling Manager Signature: 5l Phone: 276 -7600 Date: 1/29/2010 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 • Kanyer, Christopher V From: PORHOLA, STAN T Sent: Thursday, January 21, 2010 12:00 PM To: Kanyer, Christopher V Subject: FW: SLU 41 -33RD (PTD 209 -010) 10-407 Form Can you update the new 10 -407 form with the required info, per Davies request? Stan Porhola•• Drilling Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tel 907 263 7640 Fax 907 263 7884 Cell 907 229 1769 stan.porholac chevron.com Mail Confidential Footer Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263 -7640. From: Davies, Stephen F (DOA) [mailto:steve.davies @alaska.gov] Sent: Thursday, September 03, 2009 9:26 AM To: PORHOLA, STAN T Subject: RE: SLU 41 -33RD (PTD 209 -010) 10 -407 Form Stan, Yes, box 29. The "Well tested?" question in box 29 was checked "yes ", but the remainder of that box was left blank. Were any zones other than 7502' -7511' MD tested? Thanks, Steve Davies AOGCC From: PORHOLA, STAN T [mailto:stan.porhola @chevron.com] Sent: Wednesday, September 02, 2009 4:49 PM To: Davies, Stephen F (DOA) Subject: SLU 41 -33RD (PTD 209 -010) 10 -407 Form Steve, You mentioned that there was missing Formation Test data for the 10 -407 submitted for Stump Lake SLU 41 -33 Are you only referring to Box #29 on the form? Stan Porhola•• Drilling Engineer 1 • MidContinent/Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tel 907 263 7640 Fax 907 263 7884 Cell 907 229 1769 stan.porhola @chevron.com Mail Confidential Footer Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263 -7640. 2 Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 111/10 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE October 20, 2009 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL WELL LOG TYPE ScALE LOG DATE - B-111Nt oty,' NOTES LAS PbS LRU 1A COMPLETION RECORD 5" 16-Sep-09 1 1 PDS SLU 41-33RD PERFORATION RECORD 5" 23-Jul-09 1 1 PDS TBU M-32RD RST SIGMA 5" 26-Nov-09 1 1 PDS, LAS, DLIS 116--°°'3 ft5b3 /15`?15 0 0/at -616 Please acknowledge acknowledge , 7ceipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: \ Date: - _ - ' • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. Test: U Initial U Annual U Special lb. Type Test: u Stabilized U Non Stabilized U Multipoint ❑ Constant Time ❑ lsochronal ❑ Other 2. Operator Name: 5. Date Completed: 11. Permit to Drill Number: Union Oil Company of California 7/23/2009 209 -010 3. Address: 6. Date TD Reached: 12. API Number: PO Box 196247, Anchorage, AK 99519 March 12, 2009 50- 283 - 20055 -01 4a. Location of Well (Governmental Section): 7. KB Elevation (ft): 13. Well Name and Number: Surface: 772' FNL, 505' FEL, Sec 33, T14N, R8W, SM 45.1 ft above MSL Stump Lake Unit (SLU) 41 -33RD Top of Productive Horizon: 8. Plug Back Depth(MD +TVD): 14. Field /Pool(s): 563' FSL, 1647' FEL, Sec 28, T14N, R8W, SM 8355' MD (7732' TVD) Stump Lake Unit (SLU) 41 -33RD Total Depth: 9. Total Depth (MD + TVD): 550' FSL, 1637' FEL, Sec 28, T14N, R8W, SM 10,160'MD (9537' TVD) Undefined Gas 4b. Location of Well (State Base Plane Coordinates): 10. Land Use Permit: 15. Property Designation: Surface: x- 375758 y- 2655295 Zone- 4 N/A ADL- 058790 [Stump Lake Unit] TPI: x- 374631 y- 2656642 Zone- 4 16. Type of Completion (Describe): Total Depth: x- 374638 y- August 7, 9173 Zone- 4 Perforated casing 17. Casing Size Weight per foot, Ib. I.D. in inches Set at ft. 19. Perforations: From To 7- 5/8 "/7" 29.7/26 6.875/6.276 6120' 7502' - 7511' RECEIVED 18. Tubing Size Weight per foot, Ib. I.D. in inches Set at ft. 3 -1/2" 9.2 2.992 5,003' -9128' OCT 0 9 2009 20. Packer set at ft: 21. GOR cf /bbl: 22. API Liquid Hydrocardbons: 23. Specifi ra i J i FI G : 5003' n/a n/a Alaska WI Gas a N. Cormnission 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: 24d. Barometric Press ure7ap 0r89@ 0 Tubing ❑ Casing 130 F° 3800 psia @ Datum 6890 TVDSS 14.7 psia 25. Length of Flow Channel (L): Vertical Depth (H): Gg: % CO % N2: % H Prover: Meter Run: Taps: n/a n/a 0.56 0 0 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice psig Hw F° psig F psig F Hr. Size (in.) Size (in.) 1. X 16 825 66 0 na 0 2. X 12 980 66 0 na 2 3. X 11 1024 69 0 na 2 4. X 7 1224 72 0 na 2 5. X 4 1370 78 0 na 2 Basic Coefficient Flow Temp. Super Comp. Pressure Gravity Factor Rate of Flow No. (24 -Hour) hw Pm Factor F Factor (� Mcfd Fb or Fp Ft g Fpv 1. 310 2. 610 3. 920 4 940 5 1140 Temperature for Separator for Flowing No. Pr T Tr z Gas Fluid Gg G 1. 2. 3. Critical Pressure 4. Critical Temperature 5. r ,rq Form 10 -421 Revised 1/2004 CONTINUED ON REVERSE SIDO:L P. D of y( tP "1uplicate ,/1 Pc 1844 p 3400336 • Pf 3807 pf 14493249 No. Pt Pt Pc Pw Pw Pc Ps Ps Pf -Ps 1. 2. 1370 1876900 1523436 2045 4182025 - 78168 3415 11662225 362593 3. 1224 1498176 1902160 2035 4141225 - 740889 3259 10621081 423448 4. 1024 1048576 2351760 2022 4088484 - 688148 3046 9278116 476749 5. 825 680625 2719711 2010 4040100 - 639764 2835 8037225 529624 25. AOF (Mcfd) 4,555 n 1.607 Remarks: The wellbore had a fluid level of 2355'. This clearly effects the quality of this analysis. These results attempted to take into account the fluid level by adjusting the pressures to reflect. But the value of n >1 shows liquid interference in these test results. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (1 �� : "� Title Petroleum Engineer Date 10/9/2009 DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd / - hwPm Fp Basic critical flow prover or positive choke factor Mcfd /psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor = dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air = 1.000), dimensionless Gg Specific gravity of separator gas (air = 1.00), dimensionless GOR Gas -oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet (MD) n Exponent (slope) of back - pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut -in wellhead pressure, psia Pf Shut -in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless • Recommended procedures for tests and calculations may be found in the Manual of Back- Pressure Testing of Gas Wells , Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Revised 1/2004 Side 2 • FLOW RECORD • Stump Lake 41 -33 Muliti Point Test FLOWING Pipe Line PSI GAS RATE TBG CSG Differintial TEMP, DEG Pressure after at the Enstar Date TIME MMCFD PRESS PRESS Staic pen pen F Coefficient SDV 600 w meter COMMENTS 8/3/2009 9:52 1.14 825 0 7.40 4.00 66 821 812 Started test put choke on a 16 10:10 0.90 861 0 7.40 3.00 66 819 810 @10:12 reduced choke to14 10:15 0.90 882 0 7.40 3.00 66 819 810 @10:16 reduced choke to13 _ 10:21 0.90 912 0 7.40 3.00 66 818 810 @10:30 reduced choke to12 10:35 0.90 9 *50 0 7.39 3.03 66 817 808 10:46 0.95 968 0 7.35 3.20 66 816 807 @10:55 reduced choke to11.5 10:56 0.90 980 0 7.35 3.05 66 815 807 11:15 0.93 988 0 7.35 3.10 66 815 806 11:30 0.95 1002 0 7.35 3.20 66 814 805 @11:38 reduced choke to 11 11:45 0.90 1015 0 7.35 3.05 66 813 804 12:00 0.91 1020 0 7.35 3.08 67 813 804 12:15 0.93 1023 0 7.35 3.10 68 812 803 12:30 0.93 1025 0 7.35 3.10 68 811 801 12:45 0.92 1024 0 7.34 3.12 68 809 801 13:00 0.92 1025 0 7.34 3.12 68 809 800 13:15 0.93 1024 0 7.34 3.14 69 808 799 13:30 0.92 1024 0 7.34 3.12 69 807 799 13:45 0.92 1024 0 7.34 3.14 69 806 798 14:00 0.60 _ 1109 0 7.31 1.90 70 805 797 _ @13:47 reduced choke to 8 14:15 0.60 1164 0 7.30 1.90 _ 70 804 796 @13:56 reduced choke to 7.25 14:30 0.61 1196 0 7.30 1.90 71 803 795 A14:09 reduced choke to 7 14:45 0.62 1210 0 7.30 1.92 71 802 _ 794 15:00 0.62 1217 0 7.30 1.92 71 802 794 15:15 0.61 1221 0 7.30 1.90 71 803 795 15:30 0.62 1223 0 7.30 1.92 71 803 795 15:45 0.63 _ 1224 0 7.30 1.94 72 803 795 16:00 0.62 1226 0 7.30 1.92 73 803 795 _ 16:15 0.62 1226 0 7.30 1.92 73 803 795 @16:20 reduced choke to 4 16:30 0.30 1291 0 7.30 0.50 74 802 795 16:45 0.31 1343 0 7.30 0.70 75 802 795 17:00 0.31 1357 0 7.30 0.70 75 802 795 17:15 0.31 1365 0 7.30 0.70 76 802 796 17:30 0.31 1370 0 7.30 0.70 76 802 796 17:45 0.31 1372 0 7.30 0.70 77 802 796 18:00 0.30 1374 0 7.30 0.50 77 803 796 18:15 0.31 1376 0 7.30 0.70 77 _ 802 795 18:30 0.31 1376 0 7.30 0.70 78 802 795 Finshed test 0:/Forms/Oil Well Stuff/Hotsheet.xls SLU 41 -33RD 7511MD Perfs Assuming fluid in wellbore @ 2355' Multi -rate Flow Test (8/3/2009) Gas Flowing Shut -in Choke Flowrate Flowing BHP BHP Size Q WHP (Ps) (Pf) DD (Pf ^2 -Ps ^2) AOF • (1/64 ") (Mscf /d) (psia) (psia) (psia) ( %) (psia ^2 x 10e3) n (Msc /d) 4 310 1,370 3,415 3,807 10.3 2,831 1.607 4,280 7 610 1,224 3,259 3,807 14.4 3,872 1.607 5,090 11 920 1,024 3,046 3,807 20.0 5,215 1.607 4,757 12 940 980 2,999 3,807 21.2 5,499 1.607 4,463 16 1,140 825 2,835 3,807 25.5 6,456 1.607 4,183 Ave 4,555 SI WHP AOF ( 4,542 I 1,844 0.0 3,807 100.0 14,493 From AOF Plot: From Form 10 -421: y = 11.74 *x ^0.7073 AOF = Q *[Pf ^2 /(Pf ^2- Ps ^2)] ^n (Pf ^2 -Ps ^2) = 11.74 *Q ^0.7073 (Pf ^2) = 11.74 *AOF ^0.7073 • AOF = [(Pf ^2)/11.74] ^(1/0.7073) a = 76.916 b = 0.6221 SLU 44 -33RD 100,000 i _......... Multi -Rate Flow Test — —Least Squares Best Fit . • ■ [FBHP = 0.0 psia 10,000 K N CU Q N = 76.916x .6221 R 0.9767 CNI 1,000 • Theoretical Absolute Open Flow (AOF) 4.5 MMscf /d 100 1,000 10,000 100,000 GAS RATE (Mscf /d) SLU 41 -33RD 7511MD Perfs Assuming NO fluid in wellbore Multi -rate Flow Test (8/3/2009) Gas Flowing Shut -in Choke Flowrate Flowing BHP BHP Size Q WHP (Ps) (Pf) DD (Pf ^2 -Ps ^2) AOF (1/64 ") (Mscf /d) (psia) (psia) (psia) ( %) (psia ^2 x 10e3) n (Msc /d) • 4 310 1,370 1,581 3,807 58.5 11,994 10.695 2,348 7 610 1,224 1,411 3,807 62.9 12,502 10.695 2,963 11 920 1,024 1,179 3,807 69.0 13,103 10.695 2,705 12 940 980 1,128 3,807 70.4 13,221 10.695 2,511 16 1,140 825 949 3,807 . 75.1 13,593 10.695 2,264 Ave 2,558 SI WHP AOF ( 2,537 I 1,844 0.0 3,807 100.0 14,493 From AOF Plot: From Form 10 -421: y = 11.74 *x ^0.7073 AOF = Q *[Pf ^2 /(Pf ^2- Ps ^2)] ^n (Pf ^2 -Ps ^2) = 11.74 *Q ^0.7073 (Pf ^2) = 11.74 *AOF ^0.7073 AOF = [(Pf ^2)/11.74] ^(1/0.7073) • a = 6964 b = 0.0935 SLU 14-33RD AOF PLOT 100,000 - iJ , 1 -, ii — H Multi-Rate Flow Test I _____ —Least Squares Best Fit 1 i , I • I I , FBHP = 0.0 psia 1 . , ..- ...--T ,„,,■----.......■,_ 1 c -,;- 10,000 - 0 so --- , t- x Csi _ CU I Csi < ' O- a Csi . < . 1,000 y = 6963.5x° CI935 OP _ii i ' R 0.9581 7 ; i I i _i__ i 1 ■ 1 Theoretical Absolute Open Flow (AOF) I 1 = 2.2 MMscf/d - I I I i 100 I i 1 1,000 10,000 100,000 GAS RATE (Mscf/d) , ''" 7 g qx 7 5 1/k STATE OF ALASKA -; It , ooq ALAS OIL AND GAS CONSERVATION COMMISS ON WELL COMPLETION OR RECOMPLETION REPOR AN'D L T OG-- ~-' . ° i' 1a. Well Status: Oil ❑ Gas El , Plugged ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development El • Exploratory ❑ GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other ❑ No. of Completions: 1 Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Union Oil Company of Califomia Aband.: 7/23/2009 • 209 -010 • 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, Alaska, 99519 2/22/2009 50- 283 - 20055 -01 • 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 772' FNL, 505' FEL, Sec 33, T14N, R8W, SM • 3/12/2009 • Stump Lake Unit (SLU) 41 -33RD Top of Productive Horizon: 8. KB (ft above MSL): 45.1 • 15. Field /Pool(s): 563' FSL, 1647' FEL, Sec 28, T14N, R8W, SM Ground (ft MSL): 28.3 • Stump Lake Unit Total Depth: 9. Plug Back Depth(MD +TVD): 550' FSL, 1637' FEL, Sec 28, T14N, R8W, SM 8,355' MD (7,732' TVD) Undefined Gas • 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 375758 • y- 2655295 • Zone- 4 • 10,160' MD (9,537' TVD) . ADL- 058790 [Stump Lake Unit] TPI: x- 374631 y- 2656642 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 374638 • y- 2656629 • Zone- 4 N/A N/A 18. Directional Survey: Yes 0 No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained (List all Togs here and submit electronic and printed information per 20 AAC 25.071): . 77u 2 . it 1-FA;) ' ftb LWD [8 -1/2" GR -Res, 6 -1/8" GR- Res - Den -Neu]; Open Hole [GR -Res, Den, Neu, Son]; Cased Hole [GR, Son, CBL] z6"7 Cjv'D 22. CASING, LINER AND CEMENTING RECORD t' k °3 / -d- WT. PER SETTING DEPTH MD / SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 30 129 X -56 0 77' 0 77' Driven N/A 0 20 68 L -80 0 424' 0 424' 26" 152 / 68 bbl (540 / 240 sx) 0 13 -3/8 40 L -80 0 2,512' 0 2,512' 17 -1/2" 563 / 14 bbl (2000 / 50 sx) 0 9 -5/8 26 L -80 0 2,884' / 0 2,884' 12 -1/4" 93 bbl (330 sx) 0 7 -5/8/7 29.7/26 L -80 0 6,120' 0 5,506' 8 -1/2" 95 bbl (412 sx) / 0 3 -1/2 9.2 L -80 5,003' 9,128' / 4585 8,505' 6 -1/8" 152 bbl (450 sx) / 0 23. Open to production or injection? Yes 0 • No ❑ If Yes, list each 24. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 2.5" guns 6spf 7,502'- 7,511' (6,879' - 6,888' TVD) • 3 -1/2" 5,003' 5,003' 1.660" (Heater String) 2,986' N/A 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A Flowing Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 8/19/2009 24 Test Period 0 1,206 0 0 0 Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 1,550psi Opsi 24 -Hour Rate •••► 0 1,206 • 0 N/A 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Ei • Sidewall Cores Acquired? Yes ❑ No El • If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ROOKS BF L.. SEP 0 2 2009 L ;_.. -- Form 10 -407 Revised 2/2007 CONTINUED ON REVERSE A Q'. 3464 6 • • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? 151 .Yes ❑ No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top N/A N/A needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base N/A N/A Beluga Coal 5,912' 4,854' Lower Sterling 5,980' 4,897' Sterling 58 -4T 6,125' 4,997' Beluga - Top 6,427' 5,225' Beluga 71 -3ST 6,514' 5,294' Beluga 83 -0ST 8,405' 6,874' Formation at total depth: Tyonek • 10,160' 9,537' 30. List of Attachments: Operations Summary, Directional Survey, Mud Weight vs. Depth Chart, Wellbore Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola 263 -7640 Printed Name: Timothy C. Brandenburg Title: Drilling Manager Signature: 41111111111 — Phone: 276 -7600 Date: 8/20/2009 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for 1 njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Chevron • %. Chevron - Alaska %. Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SLU 41 -33RD STUMP LK UNIT 41 -33 ADL058790 5028320055 QB1675 39.37 Jobs Primary Job Type Job Category Objective Actual Start Date Actual End Date Sidetrack and Complete Sidetrack Drill Sidetrack and Complete 2/24/2009 6/22/2009 Primary Wellbore Affected Wellbore UWI Well Permit Number SLU 41 -33RD 5028320055 -01 1760860 Daily Operations . 2/24/2009 00:00 - 2/25/2009 00:00 Operations Summary P/U directional BHA w/ mud motor w/ 1.5 AKO, MWD, LWD (GR -Res), and UBHO. TIH t/2843'. POOH, racking back drillpipe. MW = 9.3 ppg. 2/28/2009 00:00 - 2/26/2009 00:00 Operations Summary . RIH and orient w/ gyro. RIH and run thru window f/2867' t/2884'. Ream undergauge hole t/2908'. Directionally drill f/2908' t/3706', orienting using gryo. MW= 9.2 ppg. 2/26/2009 00:00 - 2/27/2009 00:00 Operations Summary Take gyro surveys f/3585' t/2800. POOH. R/D wireline. Directionally drill f/3706' t14563'. Short trip f/4563' t/2848'. Pull 15k overpull f/4016' t/4006'. Pull 5 -10k drag f/3958' t/3942'. No drag thru window. Ream f/4470' t/4563'. Directionally drill f/4563' t/5251'. MW = 9.2 ppg. 2/27/2009 00:00 - 2/28/2009 00:00 Operations Summary Directionally drilled f/5251' t/5680'. Pull 20k overpulls f/5575' t/5533'. Reamed until pulled clean. Directionally drilled f/5680' t/6123'. Wiper trip t/4468'. Pull 10 -15k overpulls f/6160' t/6110'. RIH t/5592'. Ream f/5592' t16089'. Ream to bottom at 6123'. Spot baratrol (coal stabilizer) pill on bottom. POOH. Pull 15k overpull at 4320'. Pull 15k overpull at 4200'. Pull 20k drag f/4181' t/4086'. No drag thru window. MW = 9.4 ppg. 2/28/2009 00:00 - 3/1/2009 00:00 Operations Summary UD BHA. Change top pipe rams to 7" casing rams. Test 7" casing rams to 250/4000 psi for 5 min - test OK. R/U to run 7 "x7 -5/8" casing. RIH w/ 7" 26.0# L -80. Saw 3k drag thru window f/2867' t/2884'. Set down 20k at 4188' and work thru. Run 7" t/6064'. P/U crossover f /7" t/7 -5/8 ". Run 7 -5/8" 29.7# L -80 casing (3 joints) t/6109'. Break circ and wash down f/6109' t/6120'. Seeing some packoff and overpulls while working pipe. Lost hole t/6100'. Work down t/6120'. Unable to work deeper. MW = 9.2 ppg. 3/1/2009 00:00 - 3/2/2009 00:00 Operations Summary N/U cement head. Test cement lines to 4200 psi - test OK. Mix and pump 40 bbl 11.0 ppg spa bbl ( 12 sx) 15.8 ppg Class G cement. Drop top plug. Chase plug w/ 5 bbl water and displace w/ mud. Pumped 223 bbl total displacement. D' not bump ug. Set down 85k on casing slips for 7 -5/8 ". Test to 500 psi - test OK. P/U BOPE stack. Make cut on 7 -5/8" and dress casing stub. Lift B e final cut on 7 -5/8 ". Remove spacer spool. Install new Vetco 11" 5M tubing spool. Test spool t/ 250/3800 psi for 30 min - test OK. Re- install BOPE stack. Change out 7" casing rams to 2 -7/8" x 5" variable rams in upper cavity. R/U to test BOPE. Notified John Crisp w/ AOGCC on upcoming BOPE test. MW = 9.5 ppg. --` 3/2/2009 00:00 - 3/3/2009 00:00 Operations Summary Perform BOPE test to 250/4000 psi. Lower kelly valve did not test. Replace and test new lower kelly valve - test OK. All other BOPE - test OK. Test 7" x / 7 -5/8" casing to 4000 psi for 30 min - test OK (WOC time = 31.5 hrs). P/U 6 -1/8" BHA. MW = 9.4+ ppg. 3/3/2009 00:00 - 3/4/2009 00:00 Operations Summary P/U and RIH w/ BHA. RIH and tag cement at 5767'. Clean out cement f/5767' t/5795. Tag wiper plug w/ 5k at 5795'. Drill plug and shoe track f/5795' (/6040'. Test 7 "x7 -5/8" casing to 4000 psi for 30 min - test OK. Drill shoe track f/6040' t/6120' (Hard cement f/6060' t/6120'). Clean out rathole t/6123'. Drill new formation f/6123' t16143'. POOH to casing shoe at 6120'. R/U to perform FIT /LOT. Perform FIT to 15.0 ppg EMW - test OK (9.4 ppg mud, 1604 psi, 5510' TVD shoe). MW = 9.4 ppg. 3/4/2009 00:00 - 3/5/2009 00:00 Operations Summary Drill f/6143' 06750'. MW = 9.8 ppg. Drill f/6750' t/7147'. MW = 10.0 ppg. 3/5/2009 00:00 - 3/6/2009 00:00 Operations Summary Drill f/7147' t/7479'. MW = 10.2 ppg. Drill f/7479 t/7838'. MW = 10.1 ppg. 3/6/2009 00:00 - 3/7/2009 00:00 Operations Summary Drill f/7838' t/7847'. Drill f/7847' t/8360'. MW = 10.4+ ppg. Perform short trip to 7" casing shoe. Pull 40 -50k overpull at several intervals f/8105 t/6700. Work to 7" shoe at 6120'. MW = 10.4 ppg. 3/7/2009 00:00 - 3/8/2009 00:00 Operations Summary RIH f/6120' t/8263'. Wash and ream f/8263' !/8721'. MW = 10.7+ ppg. 3/8/2009 00:00 - 3/9/2009 00:00 Operations Summary POOH for bit change. Pull 40k overpull at 8519'. POOH t/ shoe at 6120'. POOH and UD BHA. P/U mud motor w/ 6 -1/8" HCM505ZX bit. M/U MWD and LWD tools. RIH !/8665'. Ream f/8665' (/8721'. Drill f/8721' !/8731'. MW = 10.8+ ppg. 3/9/2009 00:00 - 3/10/2009 00:00 Operations Summary Drill f/8731 (/9150'. MW = 10.9 ppg. Chevron I I. Chevron - Alaska %. Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SLU 41 -33RD STUMP LK UNIT 41 -33 ADL058790 5028320055 QB1675 39.37 Daily Operations 3/10/2009 00:00 - 3/11/2009 00:00 Operations Summary Drill f/9150' t/9333'. MW = 10.9 ppg. Drill f/9333' t/9502'. MW = 11.1 ppg. 3/11/2009 00:00 - 3/12/2009 00:00 Operations Summary Drill (/9502' t/10,096'. MW = 11.1 ppg. Drill f/10,096' t/10,140'. MW = 11.4 ppg. 3/12/2009 00:00 - 3/13/2009 00:00 Operations Summary • Drill f/10,140' t/10,160'. Geologist calling TD. POOH for wiper trip. Backream tight spots at 10,055', 9930', and 9730'- 9722'. Overpull of 60k at 9567'. ✓ POOH (/8569'. RIH for wiper trip t/10,000'. Wash and ream f /10,000' t/10,060'. P/U and rotate to break from differential sticking on connections. Pump out of hole f/10,060'- 9237'. Ream f/9238' t/10,060'. Increase MW (/11.6 ppg. Circ and cond mud. MW = 11.6 ppg. 3/13/2009 00:00 - 3/14/2009 00:00 Operations Summary Circ and cond mud. Back ream f/10,160' t/9715'. Pump out of hole f/9715' t/7700'. Rotate on each connection to break differential sticking. Max overpull of 50k at 9018'. Pump and straight pull f/7700' (/7328' w/ 40 -50k overpull. Pump and straight pull f/7328' t/6120' (7" csg shoe) w/ 10 -15k overpull. Pump out of hole f/6120' t/4847'. Pump dry job. POOH to BHA. UD BHA. MW = 11.6 ppg. 3/14/2009 00:00 - 3/1512009 00:00 Operations Summary R/U wireline. M/U logging tools, SP /DSI (SP, Dipole Sonic). RIH w/ logging tools. Set down at 6245' WLM. POOH and remove centralizers. RIH and set down at 6250' WLM. Could not work passed. POOH. UD logging tools. R/D wireline. P/U cleanout BHA. RIH t/6056'. RIH f/6056' (/9620'. Saw 2k drag at 6244', and 5k drag at 6420'. Differential sticking on connections f/8300' t/9135'. Work thru 10k drag at 9135', 15k drag at 9205', and 20k drag at 9390'. Set down 20k at 9620'. Unable to work thru. M/U top drive and wash thru. RIH (/9720'. Set down 25k at 9720'. Unable to work thru. M/U top drive and wash thru. Wash t/9930'. Unable to wash thru. Wash and rotate f/9930' (/10,014'. P/U (/ 9970'. Increase MW (/11.9 ppg. Ream f/9970' (/10,060' (reaming tight). MW = 11.9 ppg. 3/15/2009 00:00 - 3/16/2009 00:00 Operations Summary Circ and cond mud. Increase MW to 11.9 ppg. Backream f/10,160' (/10,020'. Pump out of hole f/10,020' (/9463'. Having to rotate to break free on connections. Pump out of hole f/9463' (/8633' w/ 10 -50k overpulis. Pump out of hole f/8633' (/6087' (inside 7" shoe). Attempt to pull out of hole - well swabbing. Pump out of hole f/6087' (/1670'. Pull out of hole. Notified Chuck Scheve w/ AOGCC of upcoming BOPE test - witness waived. MW = 11.9 ppg 3/16/2009 00:00 - 3/17/2009 00:00 Operations Summary UD BHA. R/U wireline. M/U logging tools, SP /GR/Son IW and set down at 6407' WLM. POOH. Install knuckle joints in tool string. RIH and set down at 6410' WLM. POOH. R/D wireline. Test BOPE to 25 000,p(si. Test annular to 250/2500 psi. BOPE test - all test OK. R/U to run 3 -1/2" liner. RIH w/ 3 -1/2" 9.2# L -80 liner (/3409'. MW = 11.8 ppg. V 3/17/2009 00:00 - 3118/2009 00:00 Operations Summary RIH w/ 3 -1/2" liner (/6048'. RIH w/ liner on drillpipe f/6048' 1/7099'. Top drive would not rotate. POOH (/ 6048'. Service Top Drive. RIH f/6048' (/8335'. Circ btms up. Unable to break out Top Drive. Move pipe and circ while servicing Top Drive. Minimize time w/o pipe movement to 3 -5 min. Having to pull 10 -15k to pull pipe free. Complete repairs to Top Drive. RIH while circulating f/8335' (/9130'. Tight hole at 8656' and 9112'. Work pipe f/9112' (/9130'. Attempt to work passed 9130' w/o success. Tried to wash thru w/o success. MW = 11.9 ppg. 3/18/2009 00:00 - 3/19/2009 00:00 Operations Summary Continue to circ at 9130' while reciprocating pipe. Space out. P/U cement head. Drop kirksite liner setting ball. R/U cement head and cementing lines. Stage up pressure to 3000 psi. Ball on seat but not holding pressure. Unable to confirm ball shearing landing rin.. Confirm liner set w/ 30k set down. PJSM on cement job. Test cement lines to 4200 psi - test OK. Mix and pump 42 bbl 12.0 ppg spacer. Mix - - : pump 152 bbl (450 sx) 1'2.5 ppg Class G cement slurry. Drop wiper dart. Displace cement w/ 94 bbl 6% KCI water (over displace by 4 bbl), plug not bump. Bleed off pressure, 0.25 bbl returns, check float - floats OK. CIP @ 05:30. P/U w/ liner running tool. Set ZAP liner top packer w/ 30k set d • n, gad indication of packer set. r top at 5003', liner shoe at 9128'. P/U out of liner top. Circ and pump 150 bbl fresh water. Circ out cement retu at 50 bbls away. Total of + - 62 bl cement to - surface. Mix and pump 25 bbl dirt magnet pill, follow w/ 140 bbl fresh water. R/D cement lines. UD cement head. Clean pits. POOWU drillpipe. UD liner running tool. M/U 6 -1/8" bit on drill collars, HWDP, and drillpipe (/4415'. POOH. UD drillpipe. 3/19/2009 00:00 - 3/20/2009 00:00 Operations Summary UD BHA. R/U tubing handling equipment. P/U seal assembly and locator. P/U 3 -1/2" tubing. Land locator in liner at 5009'. Test annulus to 500 psi for 5 min to confirm seals in sealbore - test OK. P/U tubing hanger, landing jt, head pin, and TIW valve. R/U lines to circ. Displace fresh water in tubing w/ 40 bbl diesel (Diesel #1, 7.2 ppg). Stab -in seals, pressure bleed to zero. Land hanger. Land locator 1' high (5009'). Clear lines. Close annular and test annulus to 500 psi for 5 min - test OK. Set BPV in 3 -1/2 ". R/U to run 1.660" heater string. P/U 1.660" tubing. Land heater string w/ 4k on hanger and w/ mule shoe at 2986'. Install TWC in 1.660 ". Pu P from 3 -1/2 ". Install TWC in 3 -1/2 ". Test hanger seals to 1500 psi for 5 min - test OK. Pull TWC from both strings and install BPV in both strings. /D B E. N/U dual tree. Test hanger void (/ 250/5000 psi for 30 min - test OK. Test heater string tree valves t/ 250/4000 psi for 30 min - test OK. 3/20/2009 00:00 - 3/21/2009 00:00 Operations Summary Test 3 -1/2" tree valves t/ 250/6500 psi for 30 min - test OK. Pull TWC from both strings. Test annulus to 3500 psi for 30 min - test OK. Install BPV in both strings. R/D lines. R/D Nabors #129. Demobe rig to CIRI pad next to Beluga runway. Chevron 1 • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SLU 41 -33RD STUMP LK UNIT 41 -33 ADL058790 5028320055 QB1675 39.37 Dally Oplerrations 3121/2009 00:00 - 3/22/2009 00:00 Operations Summary R/D Nabors #129. Demobe rig to CIRI pad next to Beluga runway. 3/2212009 00:00 - 3/23/2009 00:00 Operations Summary R/D Nabors #129. Demobe rig to CIRI pad next to Beluga runway. 3/23/2009 00:00 - 3/24/2009 00:00 Operations Summary R/D Nabors #129. Demobe rig to CIRI pad next to Beluga runway. Final rig loads off Stump Lake pad. Cleaning location. Moving misc. loads off location. 3/24/2009 00:00 - 3/25/2009 00:00 Operations Summary R/U test pump on SLU 41 -33RD. Test 3 -1/2" tubing to 4050 psi for 30 min, lost 105 psi - test OK. R/U slickline, test lubricator to 1500 psi - test OK. RIH w/ 2.84" guage ring. Set down at 5042' RKB. Work thru 1 time to get thru. Set down at 5107' RKB. Work thru 1 time to get thru. Set down at 8749' RKB. Work down to 8757' RKB. Setting down hard. POOH w/ guage ring. No metal marks on gauge ring. Recovered small piece of teflon. RIH w/ 2" drive down bailer w/ 5' barrel to 8759' RKB. Work to 8761' RKB. POOH. Recovered bailer 2/3 full of sand and a piece of teflon. RIH w/ 2 -1/2" drive down bailer w/ 6' barrel to 8759' RKB. wok to 8776' RKB. POOH. Recovered bailer 1/2 full of sand and a piece of teflon. RIH w/ 2 -1/2" drive down bailer to 8776' RKB. Work to 8870' RKB. POOH. Recovered bailer 1/2 full of sand. R/D slickline for evening due to high winds. 3/25/2009 00:00 - 3/26/2009 00:00 Operations Summary R/U test pump on SLU 41 -33RD. Test 3 -1/2" tubing to 4000 psi for 15 min - test OK. R/U slickline, test lubricator to 3500 psi - test OK. RIH w/ 2 -1/2" drive down bailer to 8862' RKB. Work bailer. Saw small overpulls while working bailer. POOH. Recovered 1/2 full of fine sand in heavy wax -like substance. RIH w/ 2 -1/2" drive down bailer to 8865' RKB. Work to 8872' RKB. POOH. Recovered 1 cup of fine sand and wax. RIH w/ 2 -1/2" drive down bailer to 8668' RKB. Work to 9093' RKB. Setting down hard, unable to work deeper (should be at landing collar). POOH. Recovered metal packer debris, set screw, and broken brass rings. RIH w/ 2.84" gauge ring to 9093' RKB. Did not see any obstructions on way down. POOH. RIH w/ 2.54" dummy gun to 9093' RKB. No problems. POOH. R/D slickline. Test 3 -1/2" tubing to 4000 psi for 30 min - lost 125 psi - test OK. R/D test pump. Secure well. 4/3/2009 00:00 - 414/2009 00:00 Operations Summary MIRU E -line unit to Stump Lake pad. SDFN. 4/4/2009 00:00 -4/6/2009 00:00 Operations Summary MIRU E -line. R/U and test lubricator 250/4000 psi - test OK. RIH w/ Sonic/CBL/GR/CCL. Log from 9080' RKB to 5000' RKB. Note cement top at 5810' RKB, base of cement at 8950' RKB from cement bond log. POOH w/ logging tools. R/D lubricator. R/D E -line. 4/5/2009 00:00 - 4/6/2009 00:00 Operations Summary R/U E -line. Test lubricator to 250psi /4,000psi - test OK. Set Halliburton 3 -1/2" EZ Drill Bridge plug at 9058' RKB ELM. Dumped 25' cement on bridge plug. Estimated top of Cement at 9033' RKB ELM. POOH. R/D lubricator. R/D E -line. 4/6/2009 00:00 - 4/7/2009 00:00 Operations Summary Wait -on- weather for flight out of Beluga to Kenai. SDFN. 4/11/2009 00:00 - 4/12/2009 00:00 Operations Summary R/U slickline. M/U lubricator and test to 500 psi - test OK. RIH w/ 1 -1/2" Kuster sample bailer to 4500', 6150', 6600', 7700', 8540', and 8895' RKB. Collect fluid samples. POOH. 4/12/2009 00:00 - 4/13/2009 00:00 Operations Summary SIMOPS w/ production. R/U to displace heater string w/ glycol. Work to displace heater string annulus to glycol. 4113/2009 00:00 - 4/14/2009 00:00 Operations Summary SIMOPS w/ production. R/U to displace heater string w/ glycol. Work to displace heater string annulus to glycol. 4/14/2009 00:00 - 4/15/2009 00:00 Operations Summary SIMOPS w/ production. R/U to displace heater string w/ glycol. Work to displace heater string annulus to glycol. R/D test pump. Secure well. 4/24/2009 00:00 - 4/26/2009 00:00 Operations Summary For Cost only 5125/2009 00:00 - 5/26/2009 00:00 Operations Summary • Travel to Beluga. Set up for equipment move to Stump Lake. 5/26/2009 00:00 - 5/27/2009 00:00 Operations Summary Rig down test equipment from IRU 11 -06 and rig up test eqiupment on SLU 41 -33RD. Notify AOGCC of Upcoming tag top of cement. Witness wasY waived by Jim Regg at 09:00 5/26/2009. 5/27/2009 00:00 - 5/28/2009 00:00 Operations Summary RU Eline. Pressure test lubricator 250psi low /2500psi high. Tag Top of Cement 8988' KB, Perforate Tyonik interval 8866'- 8880' RKB w/2.5" PJ Omega 6spf 60 deg phased guns. RD Eline. Chevron • • 1 %. Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SLU 41 -33RD STUMP LK UNIT 41 -33 ADL058790 5028320055 QB1675 39.37 Daily Operations 5129/2009 00:00 - 5/30/2009 00:00 Operations Summary 6/20/2009 00:00 - 6/21/2009 00:00 Operations Summary Rig up Schlumberger E -line and function Pressure test wireline valves 250 psi low and 2500 psi high. Shell test Lubricator, wireline valves and pump -n -sub 250 psi low and 2500 psi high. SDFN. 6/21/2009 00:00 - 6122/2009 00:00 Operations Summary RIH & perforated Tyonek sand from 8462.5 to 8493.5' w/ 2.5" PJ Omega 6spf 60 deg phased guns, POOH. RD Eline. Turned well over to production. 7/15/2009 00:00 - 7/16/2009 00:00 Operations Summary RU slickline. Pressure test lubricator to 250psi low /2500psi high. RIH w/ 2.75" GR and tag at 8,892'. Set Macco plug at 8427' to Isolate Tyonik Perforations. POOH. RD slickline. 7/16/2009 00:00 - 7/17/2009 00:00 Operations Summary RU slickline. Pressure test lubricator to 250psi low /2500psi high. RIH & pull Macco plug and Redress, Rerun Macco plug & G -stop, pressure test plug to 1500 psi for 30 min. Dump bail 11' Cement on plug. POOH. RD slickline. 7/17/2009 00:00 - 7/18/2009 00:00 Operations Summary RU slickline. Pressure test lubricator to 250psi low /2500psi high. Complete dumping 33' of cement. Est top at 8393' RKB (SLM) POOH. RD slickline 7/21/2009 00:00 - 7/22/2009 00:00 Operations Summary Perform charted positive tpressure est to 2000 psi and negative test to 0 psi held each for 30 minutes (Good Test). Witness waived by AOGCC Jim Regg. 7/22/2009 00:00 - 7/23/2009 00:00 Operations Summary RU slickline, pressure test lubricator to 250psi low /2500psi high. RIH w/ 2.74" GR & tag cement at 8355' RKB SLM, POOH. Swabbed fluid level to 2400' +/- RKB SLM. RD slickline. 7/23/2009 00:00 - 7/24/2009 00:00 Operations Summary RU Eline. Pressure test lubricator to 250psi low /2500psi high. Perforated Beluga sand from 7,502'- 7,511 RKB ELM w/ 2.5" Powerjet Omega 6spf 60 deg phased guns. RD Eline. Turn well over to posiuction. Chevron 413D Pill # !pit Lease ermit 8 to SerDrial #: : ADL - - 05 8790 Field: I Stump Lake Unit API #: 50 -283- 20055 -01 ORIGINAL RIG Surface Location. Well Classification: Development Gas Well ELEVATIONS 773' FNL 8 495' FEL Total Depth: 10,160' Sec 33,T14N,R8W,SM PBTD: 9,033' RKB -GL X: ASP4 375,758 Tubing (LS): 3 -W, 9.28, L -80, TC -II 16.80' Y: ASP4 2,655,295 Tubing (Heater): 1.660 ", 3.028, L -80, BTS -8 RKB -MSL i - — Well Status: Suspended Prod Pkrs: (1) 7" Baker "ZXP" Liner Top Pkr 45 _ Operator: UOCC Ownership: Union Oil Company of California 100% GL -MSL: 28.30' Spud Date: 2/23/09 1:00 PM RKB -MSL: 45.10' Other: Spud Feb 2009; Rig Release Mar 2009; SL Mar 2009, E -line Apr 77' Csg BHP: 4265 psi @ 10,160' MD 2009 BHT: 133° 10,160' MD e 424' Csg Description Weight Grade Conn ID Length Top Btm TOC lir= 467' Bowl Structural 30" N/A N/A Weld NA 77' 0' 77' Driven 32.0 hrs Surface 20" 94.0# H -40 BTC 19.124" 424' 0' 424' Surf 77.5 hrs • Intermediate 13 3/8" 72.0# N -80 BTC 12.347" 2,512' 0' 2,512' Surf 240.8 hrs Intermediate 9 5/8" 43.5# N -80 BTC 8.755" 2,884' 0' 2,884' Surf 580s hrs 2.512' Csg A • I` Production 7 -5/8" 29.7# L -80 BTC -Mod 6.875" 123' 0' 123' - 180.0 hrs Production 7" 26.0# L -80 BTC -Mod 6.276" 5,997' 123' 6,120' 2,196' 180.0 hrs Liner 3 1/2" 9.2# L -80 IBT -Mod 2.992" 4,125' 5,003' 9,128' 5,003' 0.0 hrs 2,884' Csg 2,196' Cale TOG Tubing 31/2" 9.28 L -80 TC -II 2.992" 5,003' 0' 5,003' 15.8 ppg 412 sx Heat string 1.660" 3.02# L -80 BTS -8 1.278" 2,986' 0' 2,986' Jewelry & Fish Description Depth Length ID OD 5,003' TOL '. '� #' 1 Tubing Hanger, Dual FTC- D- DFF6H, 3 -1/2" MCA, 1.900" IJ Lift Threads 17.5' 0.97' - - . 2 7" Baker ZXP packer (set 3/18/09) 5,003' 14.81' 5.250" 6.000" © 3 7 "x5" Baker Flex -Lock III liner hanger (set 3/18/09) 5,018' 7.30' 5.250" 5.910" 0 4 Baker Model 80 -40 Sealbore w/ GBH -22 Seal Assembly 5,025' 8.45' 4.000" 5.000" 5 Slip -Stop, Macco Pack -off, Slip -Stop w/ cement SL dump bailed(7/16/09) 8,426' - - - ' I 6 Bridge Plug w/ 45' cement dump bailed (set 4/5/09) 9,033' 27.87' - - 5,810' TOC (CBL) ' 7 PBTD - Top of 3 -1/2" Float equipment (tag 3/25/09) 9,093' - - - 12.5 ppg 450 sx 6,120' Csg 5,937' 10' Pup Jt • 6,718' 10' Pup Jt • • Petforatfons Zone I Top I Btm I Amt I Gun Size I SPF I Phase (Status I Date 7,562' 10' Pup Jt Beluga /Tyonek A Beluga 7,502' 7,511' 9' 2.5" 6 60 deg 7/23/2009 B Tyonek 8,462.5' 8,494' 30' 2.5" 6 60 deg Isolated 6/21/2009 — • 0 B Tyonek 8,866' 8,880' 14' 2.5" 6 60 deg Isolated 5/27/2009 Tag TOC @ 8355' RKB SLM 7/22/09 8,406' 10' Pup Jt r, . i0 0 8,950' BOC (CBL) ") 0 6% KCL 8.6 ppg 9,128' Csg 6 -1/8" open hole MUD 11.9 ppg 10160' TD Well Schematic Prepared By CVK 8/20/09 Chevron %. %0 SLU 41 -33RD Survey Report Schlumberger Report Date: 12- Mar -09 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski . Client: Chevron Vertical Section Azimuth: 319.380° Field: Stump Lake Unit Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: Stump Lake Unit / 41 -33 TVD Reference Datum: KB Well: SLU 41 -33 TVD Reference Elevation: 44.70 ft relative to MSL Borehole: 41 -33RD Sea Bed 1 Ground Level Elevation: 28.30 ft relative to MSL UWIIAPI#: 502832005501 Magnetic Declination: 19.051 Survey Name /Date: 41 -33RD / February 12, 2009 Total Field Strength: 55760.172 nT Tort I AHD 1 DDI I ERD ratio: 124.819° / 1844.59 ft / 5.390 / 0.193 Magnetic Dip: 74.086° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet . Declination Date: February 22, 2009 Location LaNLong: N 61.26582820, W 150.70584335 Magnetic Declination Model: BGGM 2008 Location Grid NIE YIX: N 2655295.200 ftUS, E 375758.030 ftUS North Reference: True North . • Grid Convergence Angle: - 0.61893279 Total Corr Mag North -> True North: +19.051° Grid Scale Factor: 0.99991756 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub -Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting • Latitude Longitude Depth True Section Departure True North True North (ft ) (deg) _ (deg) (ft ) (ft ) (ft) (ft ) (ft) (ft) (ft ) (deg1100ft ) (ftUS) (ftUS) KBE 0.00 0.00 0.00 -44.70 0.00 0.00 0.00 0.00 0.00 0.00 0.00 • 2655295.20 • 375758.03 N 61.26582820 W 150.70584335 CNSG +DPIPE (gyro) 200.00 0.07 55.43 155.30 200.00 -0.01 0.12 0.12 0.07 0.10 0.04 2655295.27 375758.13 N 61.26582839 W 150.70584278 400.00 0.21 109.13 355.30 400.00 -0.34 0.58 0.55 0.02 0.55 0.09 2655295.21 375758.58 N 61.26582825 W 150.70584024 600.00 0.66 119.19 555.29 599.99 -1.74 2.10 2.01 -0.66 1.90 0.23 2655294.52 375759.92 N 61.26582638 W 150.70583257 800.00 0.77 189.57 755.28 799.98 -3.68 4.30 3.70 -2.55 2.68 0.41 2655292.62 375760.68 N 61.26582122 W 150.70582812 1000.00 1.14 194.58 955.25 999.95 -5.68 7.63 6.12 -5.80 1.96 0.19 2655289.38 375759.92 N 61.26581233 W 150.70583224 1200.00 1.30 191.58 1155.21 1199.91 -8.20 11.89 10.00 -9.95 1.00 0.09 2655285.24 375758.92 N 61.26580099 W 150.70583767 1400.00 1.49 174.80 1355.15 1399.85 -11.71 16.72 14.78 -14.76 0.78 0.22 2655280.43 375758.65 N 61.26578782 W 150.70583892 1600.00 0.64 161.58 1555.11 1599.81 -14.87 20.42 18.46 -18.41 1.37 0.44 2655276.78 375759.20 N 61.26577784 W 150.70583557 1800.00 0.53 177.67 1755.10 1799.80 -16.63 22.45 20.47 -20.39 1.76 0.10 2655274.79 375759.57 N 61.26577241 W 150.70583335 2000.00 0.71 227.02 1955.09 1999.79 -17.40 24.49 22.18 -22.16 0.89 0.27 2655273.03 375758.68 N 61.26576758 W 150.70583829 2200.00 0.87 221.64 2155.07 2199.77 -17.66 27.24 24.16 -24.14 -1.02 0.09 2655271.07 375756.75 N 61.26576216 W 150.705849 2400.00 0.90 233.55 2355.05 2399.75 -17.75 30.32 26.42 -26.21 -3.30 0.09 2655269.03 375754.45 N 61.26575651 W 150.70586 2600.00 0.84 228.85 2555.03 2599.73 -17.65 33.36 28.67 -28.11 -5.66 0.05 2655267.16 375752.06 N 61.26575131 W 150.70587 2730.00 0.72 183.37 2685.02 2729.72 -18.25 35.04 30.24 -29.55 -6.43 0.47 2655265.72 375751.28 N 61.26574737 W 150.70587988 TOW @2867'md - 2800.00 0.54 147.31 2755.01 2799.71 -18.89 35.78 30.91 -30.27 -6.28 0.61 2655265.00 375751.43 N 61.26574541 W 150.70587901 2900.00 2.13 22.96 2854.99 2899.69 -18.53 37.60 29.43 -28.95 -5.30 2.48 2655266.31 375752.42 N 61.26574900 W 150.70587345 3000.00 5.09 16.65 2954.78 2999.48 -15.30 43.89 23.23 -22.99 -3.30 2.98 2655272.25 375754.48 N 61.26576531 W 150.70586211 3100.00 6.31 0.83 3054.29 3098.99 -8.78 53.76 13.39 -13.24 -1.95 1.98 2655281.98 375755.94 N 61.26579197 W 150.70585443 3200.00 9.96 345.60 3153.28 3197.98 3.10 67.83 4.07 0.63 -4.02 4.21 2655295.88 375754.02 N 61.26582993 W 150.70586620 3300.00 12.67 335.97 3251.33 3296.03 21.37 87.40 21.80 19.03 -10.64 3.29 2655314.34 375747.60 N 61.26588025 W 150.70590380 3400.00 15.98 327.67 3348.22 3392.92 45.51 112.10 46.48 40.69 -22.47 3.89 2655336.12 375736.00 N 61.26593948 W 150.70597101 3500.00 19.20 316.65 3443.56 3488.26 75.58 142.23 76.32 64.29 -41.13 4.62 2655359.92 375717.60 N 61.26600404 W 150.70607701 End Gyro 3585.00 23.68 311.73 3522.66 3567.36 106.47 173.28 106.75 85.83 -63.48 5.68 2655381.70 375695.49 N 61.26606295 W 150.70620395 MWD -DMAG 3623.44 24.47 313.95 3557.76 3602.46 122.05 188.96 122.19 96.49 -74.97 3.13 2655392.48 375684.11 N 61.26609211 W 150.70626923 SurveyEditor Ver SP 2.1 Bld( users) 41 -33 \SLU 41- 33 \41- 33RD \41 -33RD Generated 8/20/2009 2:54 PM Page 1 of 3 Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub -Sea TVD Closure DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North (ft ) (deg) (deg) (ft) (ft) (ft ) (ft) (ft) (ft ) (ft ) (deg1100ft )_ (ftUS) (ftUS) 3717.18 29.54 315.01 3641.25 3685.95 164.44 231.51 164.46 126.33 - 105.31 5.43 2655422.65 375654.10 N 61.26617372 W 150.70644155 3811.74 34.67 313.94 3721.33 3766.03 214.50 281.75 214.50 161.50 - 141.18 5.46 2655458.20 375618.62 N 61.26626993 W 150.70664532 3907.95 37.94 314.10 3798.85 3843.55 271.20 338.70 271.30 201.08 - 182.13 3.40 2655498.22 375578.10 N 61.26637819 W 150.70687798 4002.65 42.30 314.58 3871.25 3915.95 331.98 399.71 332.22 243.73 - 225.76 4.62 2655541.33 375534.94 N 61.26649484 W 150.70712580 4097.16 46.71 317.68 3938.64 3983.34 398.09 465.94 398.43 291.51 - 271.60 5.20 2655589.60 375489.62 N 61.26662554 W 150.70738620 4192.25 47.46 318.72 4003.39 4048.09 467.71 535.57 468.05 343.43 - 318.01 1.12 2655642.01 375443.78 N 61.26676753 W 150.70764987 4288.96 47.55 318.75 4068.72 4113.42 539.02 606.88 539.34 397.03 - 365.04 0.10 2655696.11 375397.33 N 61.26691414 W 150.70791705 4382.80 47.92 318.43 4131.84 4176.54 608.46 676.33 608.77 449.11 - 410.97 0.47 2655748.69 375351.97 N 61.26705659 W 150.70817800 4479.21 48.63 318.45 4196.00 4240.70 680.40 748.28 680.72 502.95 - 458.71 0.74 2655803.04 375304.82 N 61.26720385 W 150.70844918 4575.04 49.18 318.40 4258.99 4303.69 752.61 820.50 752.93 556.98 - 506.63 0.58 2655857.57 375257.48 N 61.26735162 W 150.70872145 4669.85 49.48 318.48 4320.78 4365.48 824.51 892.41 824.84 610.79 - 554.34 0.32 2655911.89 375210.37 N 61.26749879 W 150.70899247 4766.51 48.34 319.68 4384.31 4429.01 897.36 965.26 897.67 665.83 - 602.06 1.51 2655967.44 375163.25 N 61.26764933 W 150.709263 4863.90 48.97 319.98 4448.64 4493.34 970.47 1038.38 970.74 721.70 - 649.22 0.69 2656023.81 375116.70 N 61.26780214 W 150.7095 4957.36 48.42 320.66 4510.33 4555.03 1040.67 1108.58 1040.89 775.73 - 694.05 0.80 2656078.32 375072.46 N 61.26794992 W 150.70978 5052.56 47.07 321.17 4574.35 4619.05 1111.10 1179.04 1111.28 830.42 - 738.48 1.47 2656133.48 375028.63 N 61.26809950 W 150.71003861 5146.60 46.96 320.54 4638.47 4683.17 1179.87 1247.84 1180.01 883.77 - 781.90 0.50 2656187.29 374985.78 N 61.26824542 W 150.71028534 5243.76 44.47 322.54 4706.30 4751.00 1249.37 1317.38 1249.46 938.21 - 825.18 2.96 2656242.19 374943.10 N 61.26839431 W 150.71053119 5339.15 41.71 323.31 4775.96 4820.66 1314.40 1382.54 1314.45 990.19 - 864.47 2.95 2656294.59 374904.38 N 61.26853648 W 150.71075442 5434.02 38.22 322.68 4848.66 4893.36 1375.21 1443.47 1375.23 1038.85 - 901.13 3.70 2656343.64 374868.25 N 61.26866957 W 150.71096272 5527.65 34.02 320.98 4924.28 4968.98 1430.33 1498.65 1430.34 1082.26 - 935.19 4.61 2656387.40 374834.66 N 61.26878828 W 150.71115627 5623.05 30.11 320.28 5005.11 5049.81 1480.95 1549.28 1480.96 1121.41 - 967.30 4.12 2656426.90 374802.98 N 61.26889537 W 150.71133868 5718.36 26.46 319.57 5089.02 5133.72 1526.10 1594.44 1526.11 1155.97 - 996.36 3.85 2656461.77 374774.30 N 61.26898990 W 150.71150378 5813.51 25.31 321.10 5174.63 5219.33 1567.63 1635.97 1567.64 1187.94 - 1022.88 1.40 2656494.02 374748.13 N 61.26907733 W 150.71165446 5908.54 21.35 322.81 5261.87 5306.57 1605.22 1673.60 1605.22 1217.54 - 1046.10 4.23 2656523.87 374725.23 N 61.26915829 W 150.71178641 6005.22 18.35 317.55 5352.81 5397.51 1638.01 1706.40 1638.01 1242.80 - 1067.02 3.61 2656549.35 374704.59 N 61.26922737 W 150.71190525 6038.20 18.10 315.95 5384.13 5428.83 1648.31 1716.72 1648.31 1250.31 - 1074.08 1.70 2656556.94 374697.61 N 61.26924792 W 150.71194539 7" @ 6123'md 6133.05 18.47 318.92 5474.19 5518.89 1678.04 1746.47 1678.05 1272.23 - 1094.20 1.06 2656579.07 374677.73 N 61.26930785 W 150.71205970 MWD- Standard 6227.71 16.12 317.69 5564.57 5609.27 1706.18 1774.61 1706.18 1293.25 - 1112.90 2.51 2656600.29 374659.26 N 61.26936535 W 150.71216595 6321.90 11.37 324.61 5656.04 5700.74 1728.51 1796.96 1728.51 1310.50 - 1127.09 5.33 2656617.69 374645.26 N 61.26941253 W 150.71224657 6416.69 8.02 330.52 5749.47 5794.17 1744.31 1812.90 1744.31 1323.88 - 1135.76 3.68 2656631.16 374636.73 N 61.26944912 W 150.71229582 6511.98 3.57 321.92 5844.25 5888.95 1753.80 1822.51 1753.80 1332.01 - 1140.86 4.75 2656639.34 374631.72 N 61.26947135 W 150.71232 6607.21 0.15 46.80 5939.41 5984.11 1756.77 1825.50 1756.77 1334.43 - 1142.60 3.74 2656641.78 374630.01 N 61.26947796 W 150.71233470 6701.57 0.10 98.45 6033.77 6078.47 1756.71 1825.69 1756.71 1334.50 - 1142.43 0.12 2656641.85 374630.18 N 61.26947816 W 150.71233372 l 6794.53 0.12 1.41 6126.73 6171.43 1756.72 1825.83 1756.72 1334.58 - 1142.35 0.18 2656641.93 374630.26 N 61.26947840 W 150.71233325 6892.06 0.10 200.72 6224.26 6268.96 1756.75 1825.87 1756.76 1334.61 - 1142.37 0.22 2656641.95 374630.23 N 61.26947846 W 150.71233341 6988.14 0.08 15.68 6320.34 6365.04 1756.75 1825.88 1756.75 1334.59 - 1142.39 0.19 2656641.94 374630.22 N 61.26947842 W 150.71233348 7085.86 0.10 2.08 6418.06 6462.76 1756.85 1826.04 1756.85 1334.74 - 1142.36 0.03 2656642.09 374630.25 N 61.26947883 W 150.71233336 7180.90 0.11 129.28 6513.10 6557.80 1756.82 1826.11 1756.82 1334.77 - 1142.29 0.20 2656642.12 374630.32 N 61.26947890 W 150.71233294 7277.55 0.15 123.67 6609.75 6654.45 1756.61 1826.33 1756.61 1334.64 - 1142.11 0.04 2656641.98 374630.50 N 61.26947855 W 150.71233193 7373.18 0.08 45.53 6705.38 6750.08 1756.49 1826.50 1756.50 1334.62 - 1141.96 0.16 2656641.96 374630.65 N 61.26947849 W 150.71233107 7468.34 0.10 263.37 6800.54 6845.24 1756.55 1826.55 1756.55 1334.65 - 1142.00 0.18 2656642.00 374630.61 N 61.26947859 W 150.71233127 7564.05 0.15 346.52 6896.25 6940.95 1756.70 1826.73 1756.70 1334.77 - 1142.11 0.18 2656642.11 374630.50 N 61.26947889 W 150.71233190 7659.85 0.12 145.17 6992.05 7036.75 1756.72 1826.78 1756.72 1334.81 - 1142.08 0.28 2656642.15 374630.53 N 61.26947900 W 150.71233175 7754.24 0.11 110.77 7086.44 7131.14 1756.54 1826.96 1756.54 1334.69 - 1141.94 0.07 2656642.04 374630.67 N 61.26947869 W 150.71233094 SurveyEditor Ver SP 2.1 Bld( users) 41- 33 \SLU 41- 33 \41- 33RD \41 -33RD Generated 8/20/2009 2:54 PM Page 2 of 3 Measured Azimuth Vertical Along Hole NS EW Comments Depth Inclination True Sub -Sea TVD TVD Section Departure Closure True North True North DLS Northing Easting Latitude Longitude (ft ) (deg) (deg) (ft) (ft ) (ft ) (ft) (ft) (ft ) (ft ) (deg1100ft ) (ftUS) (ftUS) 7850.30 0.12 277.32 7182.50 7227.20 1756.53 1826.98 1756.53 1334.67 - 1141.95 0.24 2656642.02 374630.66 N 61.26947864 W 150.71233102 7945.78 0.05 281.78 7277.98 7322.68 1756.64 1827.13 1756.64 1334.69 - 1142.09 0.07 2656642.04 374630.52 N 61.26947870 W 150.71233182 8039.30 0.10 359.52 7371.50 7416.20 1756.73 1827.22 1756.73 1334.78 - 1142.13 0.11 2656642.13 374630.48 N 61.26947894 W 150.71233205 8136.24 0.12 97.07 7468.44 7513.14 1756.72 1827.37 1756.72 1334.86 - 1142.03 0.17 2656642.20 374630.58 N 61.26947914 W 150.71233148 8229.04 0.08 76.35 7561.24 7605.94 1756.62 1827.53 1756.62 1334.86 - 1141.87 0.06 2656642.20 374630.74 N 61.26947915 W 150.71233057 8323.29 0.08 8.04 7655.49 7700.19 1756.64 1827.65 1756.64 1334.94 - 1141.80 0.10 2656642.28 374630.81 N 61.26947937 W 150.71233016 8421.83 0.08 84.17 7754.03 7798.73 1756.64 1827.77 1756.64 1335.01 - 1141.72 0.10 2656642.36 374630.89 N 61.26947958 W 150.71232971 8516.81 0.03 291.54 7849.01 7893.71 1756.63 1827.81 1756.63 1335.03 - 1141.68 0.11 2656642.37 374630.93 N 61.26947962 W 150.71232947 8611.58 0.05 69.47 7943.78 7988.48 1756.63 1827.84 1756.64 1335.05 - 1141.66 0.08 2656642.39 374630.95 N 61.26947968 W 150.71232938 8705.81 0.14 35.53 8038.01 8082.71 1756.65 1827.99 1756.65 1335.16 - 1141.56 0.11 2656642.50 374631.06 N 61.26947998 W 150.71232878 8801.92 0.05 222.28 8134.12 8178.82 1756.67 1828.07 1756.67 1335.23 - 1141.52 0.20 2656642.57 374631.10 N 61.26948016 W 150.71232855 8896.51 0.52 139.69 8228.71 8273.41 1756.24 1828.51 1756.24 1334.87 - 1141.27 0.55 2656642.21 374631.34 N 61.26947918 W 150.71232 8991.25 0.27 134.37 8323.45 8368.15 1755.58 1829.16 1755.59 1334.38 - 1140.83 0.27 2656641.72 374631.77 N 61.26947785 W 150.71232 9088.11 0.73 141.21 8420.30 8465.00 1754.74 1830.01 1754.74 1333.74 - 1140.28 0.48 2656641.07 374632.32 N 61.26947610 W 150.71232152 9182.12 0.78 183.25 8514.31 8559.01 1753.68 1831.19 1753.68 1332.64 - 1139.94 0.58 2656639.96 374632.64 N 61.26947308 W 150.71231960 9276.95 0.71 176.45 8609.13 8653.83 1752.74 1832.42 1752.75 1331.41 - 1139.94 0.12 2656638.73 374632.63 N 61.26946971 W 150.71231960 9374.96 0.83 171.96 8707.13 8751.83 1751.66 1833.74 1751.66 1330.10 - 1139.81 0.14 2656637.42 374632.75 N 61.26946613 W 150.71231882 9468.94 0.51 198.62 8801.10 8845.80 1750.87 1834.82 1750.87 1329.03 - 1139.84 0.47 2656636.35 374632.70 N 61.26946320 W 150.71231904 9565.77 0.17 138.52 8897.93 8942.63 1750.51 1835.35 1750.51 1328.51 - 1139.89 0.46 2656635.84 374632.66 N 61.26946179 W 150.71231928 9659.24 0.17 195.25 8991.40 9036.10 1750.29 1835.61 1750.29 1328.27 - 1139.83 0.17 2656635.60 374632.71 N 61.26946114 W 150.71231896 9753.63 0.44 133.78 9085.79 9130.49 1749.85 1836.07 1749.86 1327.89 - 1139.61 0.41 2656635.21 374632.93 N 61.26946009 W 150.71231769 9848.21 0.65 120.79 9180.37 9225.07 1748.99 1836.97 1748.99 1327.36 - 1138.88 0.26 2656634.67 374633.65 N 61.26945865 W 150.71231358 9943.08 1.44 122.27 9275.22 9319.92 1747.34 1838.70 1747.34 1326.45 - 1137.41 0.83 2656633.75 374635.11 N 61.26945615 W 150.71230523 10038.38 1.48 139.82 9370.49 9415.19 1744.96 1841.11 1744.96 1324.87 - 1135.61 0.47 2656632.15 374636.90 N 61.26945183 W 150.71229496 Last Survey 10104.53 1.71 156.28 9436.61 9481.31 1743.16 1842.94 1743.16 1323.32 - 1134.66 0.77 2656630.58 374637.83 N 61.26944758 W 150.71228957 TD (Projected) • 10160.00 1.71 156.28 9492.06 9536.76 - 1741.58 1844.59 1741.58 1321.80 - 1133.99 0.00 • 2656629.06 . 374638.48 N 61.26944343 W 150.71228579 Survey Type: Definitive Survey NOTES: CNSG +DPIPE - ( NorthSeeking Gyro Continuous - Drillpipe -- Continuous NorthSeeking Gyro (CNSG) run in drillpipe. High - accuracy - northseeking gyro operating in "dynamic" continuous running mode. Sensor package is initialized onto a stationing survey point and run continuously in and out of the hole. Depending on survey length - intermediate stops are made for bias updates. This model applies larger • misalignment errors due to being run in the drillstring. ) 1 MWD +DMAG - ( MWD + BGGM referenced multistation interference correction -- Standard SLB MWD error model where the surveys have been corrected using the SLB multistation DMAG (DeMAGnetization) correction process to correct for drillstring magnetic interference. This model contains improved azimuth accuracy as a result of applying DMAG as published in SPE 87977. ) MWD - STD - ( MWD Standard -- Standard SLB MWD surveys which have fully met their FAC "field acceptance criteria" without any additional corrections. Legal Description: Northing (Y) (ftUS] Easting 1X1 (ftUS] Surface : 4508 FSL 505 FEL S33 T14N R8W SM 2655295.20 375758.03 BHL : 550 FSL 1637 FEL S28 T14N R8W SM 2656629.06 374638.48 SurveyEditor Ver SP 2.1 Bld( users) 41- 33 \SLU 41- 33 \41- 33RD \41 -33RD Generated 8/20/2009 2:54 PM Page 3 of 3 • • Stump Lake Unit 41 -33RD Mud Weight -vs- Depth PTD 209 -010 Mud Weight (ppg) 8 8.2 8.4 8.6 8.8 9 9.2 9.4 9.6 9.8 10 10.2 10.4 10.6 10.8 11 11.211.411.611.8 12 0 Measured Depth ..True Vertical Depth 2,000 4,000 E 5 6,000 a. o I TD 8 -1/2" Hole @ 6123' MD 8,000 10,000 I TD 6 -1/8" Hole @ 10,160' MD I 12,000 S L3 I SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION / ANCHORAGE, ALASKA 99501 -3539 A PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. Timothy C. Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: Stump Lake Unit (SLU) 41 -33rd Sundry Number: 309 -230 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, fr Daniel T. Seamount, Jr. opoi Chair DATED this day of July, 2009 Encl. 009 -00 4 1°°t jvJG - a1/ o 4/ ALASKA STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon Suspend ❑ Operational shutdown ❑ Perforate 0 Waiver ❑ Other El Alter casing❑ Repair well ❑ Plug Perforations 0 Stimulate ❑ Time Extension ❑ Change approved program❑ Pull Tubing Perforate New Pool ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 Exploratory ❑ 209 -010 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, Alaska, 99519 50- 283 - 20055 -01 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El . Stump Lake Unit (SLU) 41 -33RD 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL- 058790 [Stump Lake Unit] 45.1' MSL Stump Lake Unit, Undefined Gas 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 10,160 9,537 9,093 8,470 N/A N/A Casing Length Size MD TVD Burst Collapse Structural 77' 30" 77' 77' N/A N/A Conductor 424' 20" 424' 424' 1,530 psi 520 psi Surface 2,512' 13 -3/8" 2,512' 2,512' 5,380 psi 2,670 psi Intermediate 2,884' 9 -5/8" 2,884' 2,884' 6,330 psi 3,810 psi Production 6,120' 7- 5/8 "x7" 6,120' 5,506' 6,890 psi 4,790 psi Liner 4,125' 3 -1/2" 9,128' 8,505' 10,160 psi 10,530 psi Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 3 -1/2" LS; 1.660" HS L -80; L -80 5003' LS; 2986' HS Packers and SSSV Type: Packers and SSSV MD (ft): Baker ZAP Liner Top Packer 5003' 13. Attachments: Description Summary of Proposal El 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 - Service ❑ 15. Estimated Date for 7/1 2009 16. Well Status after proposed work: Commencing Operations: Oil ❑ Gas 0 • Plugged ❑ Abandoned ❑ 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer 263 -7831 Printed Name /� Timothy C. Brandenburg Title Drilling Manager Signature ry Phone 276 -7600 Date 7/1/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number dq . 9,3 0 CEIVFD Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ' Z© �� 'Ct' ZS*, II W) woe L( pl�1 f f , 1 g Alaska Oil 81 Gas Coti4. ,;txb: ; °i : ";i=;ar Anchorai ;' Subsequent Form Required: I 0 - 4-0 4 , RBDMS BA. JUL o 9 2009 APPROVED BY a (� f i /J fir Approved by: Ali COMMISSIONER THE COMMISSION Date: 7 / � ? 7 ik 4 =1 Form 10-403 Revised 06/2006 ORIGINAL Submit in Duplicate Chevron • • Stump Lake Unit IOW Well # SLU 41 -33RD 7/1/09 OBJECTIVE: • Abandon Tyonek & perforate Beluga zones. PROCEDURE SUMMARY: 1 RU slickline. Pressure test lubricator 250psi low /2,500psi high. 2 Attempt to push away some formation fluid. Hook up field gas line to well and pressure up to 950psi ( +I). 3 Set slickline bridge plug at 8,430' RKB ( + / -) or within 50' of perfs. 4 Dump bail at least 25' cement on top of plug at 8,430' RKB ( + / -). 5 RD slickline. 6 WOC for 24 hours. 7 Bleed well pressure off to 200 psi for charted 12 hour negative test expected differential pressure of +/- 750psi. 8 RU slickline. Pressure test lubricator 250psi low /2,500psi high. 9 RIH w/ GR and tag top of cement at 8,405' RKB ( + / -). 10 RIH w/ dummy gun to 8,405' RKB ( + / -). 11 RD slickline. 12 RU Eline. Pressure test lubricator 250psi low /2,500psi high. 13 RIH and perf Beluga sand from 7,502' RKB ( + / -) to 7,511' RKB ( + / -). 14 RD Eline. 15 Turn well over to production. SLU 41 -33RD REVISED BY: CVK 7/1/09 C h evron !pit Lake Lease Seria ADLOO 879 Field: I Stump Lake Unit API #: 50- 283 - 20055 -01 ORIGINAL RIG Surface Location: Well Classification Development Gas Well ELEVATIONS 773' FNL & 495' FEL Total Depth: 10,160' Sec 33,T14N,R8W,SM PBTD 9,033' RKB -GL . X: ASP4 375,758 Tubing (LS)' 3-Ye", 9. L -80, TC -II 16 80' Y ASP4 2,655,295 Tubing (Heater). 1 660", 3.02 #, L -80, BTS -8 RKB -MSL - Well Status: Suspended Prod Pkrs: (1) 7" Baker "ZXP" Liner Top Pkr 45.10' I I 11 Operator UOCC Ownership: Union Oil Company of California 100% GL -MSL: 28.30' Spud Date 2/23/09 1.00 PM RKB-MSL - 45.10' Other: Spud Feb 2009; Rig Release Mar 2009; SL Mar 2009; E -line 77' Csg BHP: 4265 psi @ 10,160' MD Apr 2009 BHT: 133° @ 10,160' MD CASING a Tubing Rotate 424' Cog Description Weight Grade Conn ID Length Top Btm TOC Hrs 467' Bowl Structural 30" N/A N/A Weld NA 77' 0' 77' Driven 32.0 hrs Surface 20" 94.0# H -40 BTC 19.124" 424' 0' 424' Surf 77.5 hrs Intermediate 13 3/8" 72.0# N -80 BTC 12.347" 2,512' 0' 2,512' Surf 240.8 hrs Intermediate 9 5/8" 43.5# N -80 BTC 8 755" 2,884' 0' 2,884' Surf 500.5 hrs • 2,512' Csg Production 7 -5/8" 29.7# L -80 BTC -Mod 6.875" 123' 0' 123' - 180.0 hrs Production 7" 26.0# L -80 BTC -Mod 6.276" 5,997' 123' 6,120' 2,196' 180.0 hrs Liner 3 1/2" 9.2# L -80 IBT -Mod 2.992" 4,125' 5,003' 9,128' 5,003' 0.0 hrs 2,884' Csg - 2,196' CaIc TOC Tubing 31/2" 9.2# L -80 TC -II 2.992" 5,003' 0' 5,003' 15.8 ppg 412 sx Heat string 1.660" 3.026 L -80 BTS -8 1 278" 2,986' 0' 2,986' Jewelry & Fish Description Depth Length ID OD 5,003' TOL ' I - © 1 Tubing Hanger, Dual FTC- D- OFF6H, 3 -1/2" MCA, 1.900" IJ Lift Thread, 17.5' 0.97' - - -a- 2 7" Baker ZXP packer (set 3/18/09) 5,003' 14.81' 5.250" 6.000" 1 © 3 7 "x5" Baker Flex -Lock III liner hanger (set 3/18/09) 5,018' 7.30' 5.250" 5.910" 0 4 Baker Model 80 -40 Sealbore w/ GBH -22 Seal Assembly 5,025' 8.45' 4.000" 5.000" 5 Bridge Plug w/ 45' cement dump bailed (set 4/5/09) 9,033' 27.87' - - 6 PBTD - Top of 3 -1/2" Float equipment (tag 3/25/09) 9,093' - - - 5,810' TOC (CBL) 12.5 ppg 450 sx 6,120' Csg 5,937' 10' Pup Jt ' 6,718' 10' Pup Jt Zone I Top I Btm- I Amt I Gun Size SPF Phase (Status I Date 7,562' 10' Pup Jt Beluga /Tyonek A Tyonek 8,462.5' 8,494' 30' 2.5" 6 60 deg Open 6/21/2009 B Tyonek 8,866' 8,880' 14' 2.5" 6 60 deg Open 5/27/2009 8,406' 10' Pup Jt MI 111 r, ®11 8,950' BOC (CBL) '. 3 N 4 , ;3 0 6% KCL a,5: 8.6 ppg 9,128' Csg 6 -1/8" open hole MUD , 11.9 ppg 10160' TD - Actual Well Schematic Prepared By. CVK 7 -1 -09 - ` - ' POSED Permit to Drill #: 209 -010 Chevron SLU 41 -33RD Stump Lake Unit Lease & Serial #: ADL- 058790 Field: I Stump Lake Unit API# 50- 283 - 20055 -01 ORIGINAL RIG Surface Location: Well Classification. Development Gas Well ELEVATIONS 773' FNL & 495' FEL Total Depth 10,160' Sec 33,T14N,R8W,SM PBTD 9,033' RKB -GL T X: ASP4 375,758 Tubing (LS): 3 -W, 9.2 #, L -80, TC -II 16.80' Y: ASP4 2,655,295 Tubing (Heater): 1.660 ", 3.02 #, L -80, BTS -8 RKB -MSL - - n Well Status. Suspended Prod Pkrs (1) 7" Baker "ZXP" Liner Top Pkr 45.10' . II Operator: UOCC Ownership Union Oil Company of California 100% GL -MSL: 28.30' Spud Date: 2/23/09 1:00 PM RKB -MSL. 45 10' Other. Spud Feb 2009; Rig Release Mar 2009; SL Mar 2009; E -line Apr 77' Csg ' . BHP 4265 psi @ 10,160' MD 2009 BHT: 133° @ 10,160' MD CASING & Tubing 424' Csg J Description Weight Grade Conn ID Length Top Btm TOC firs 467' Bowl Structural 30" N/A N/A Weld NA 77' 0' 77' Driven 32.0 hrs Surface 20" 94.0# H -40 BTC 19.124" 424' 0' 424' Surf 77.5 hrs Intermediate 13 3/8" 72.0# N -80 BTC 12.347" 2,512' 0' 2,512' Surf 240.8 hrs ' Intermediate 9 5/8" 43.5# N -80 BTC 8 755" 2,884' 0' 2,884' Surf 560.5 hrs 2,512' Csg A i . . ' Production 7 -5/8" 29.7# L -80 BTC -Mod 6.875" 123' 0' 123' - 180.0 hrs Production 7" 26 0# L -80 BTC -Mod 6.276" 5,997' 123' 6,120' 2,196' 180.0 hrs Liner 31/2" 9.2# L -80 IBT -Mod 2.992" 4,125' 5,003' 9,128' 5,003' 0.0 hrs 2,884' Csg 2,196' CaIcTOC Tubing 31/2" 9.28 L -80 TC -II 2.992" 5,003' 0' 5,003' 15.8 ppg 412 sx Heat string 1 660" 3.02# L -80 BTS -8 1.278" 2,986' 0' 2,986' Jewelry & Fish Description Depth Length ID OD 5,003' TOL ' LIELMJ 1 Tubing Hanger, Dual FTC- D- GFF6H, 3 -1/2" MCA, 1 900" IJ Lift Thread.: 17.5' 0.97' - - ', , © 2 7" Baker ZXP packer (set 3/18/09) 5,003' 14.81' 5.250" 6.000" 3 7 "x5" Baker Flex -Lock III liner hanger (set 3/18/09) 5,018' 7.30' 5.250" 5.910" El 4 Baker Model 80 -40 Sealbore w/ GBH -22 Seal Assembly 5,025' 8.45' 4.000" 5.000" 5 Slip -Stop, Macco Pack -off, Slip -Stop w/ 30' ( + / -) cement dump bailed 8,430'( + / -) - - - - . I . 6 Bridge Plug w/ 45' cement dump bailed (set 4/5/09) 9,033' 27.87' - - 5,810' TOC (CBL) l '.. 7 PBTD - Top of 3 -1/2" Float equipment (tag 3/25/09) 9,093' - - - 12.5 ppg 450 sx 6,120' Csg 5,937' 10' Pup Jt - ' 6,718' 10' Pup Jt Zone I Top I Btm I Amt I Gun Size SPF Phase Status I Date 7,562' 10' Pup Jt BelugalTyonek A Beluga 502'( + / -) 7.511'( + / -) 9' 2.5" 6 60 deg Proposed B Tyonek 8,462.5' 8,494' 30' 2.5" 6 60 deg Isolate 6/21/2009 B Tyonek 8,866' 8,880' 14' 2.5" 6 60 deg Isolate 5/27/2009 . 8,406' 10' Pup Jt Il 0 8,950' BOC (CBL) ew * 0 ° 0 6% KCL 8.6 ppg 9,128' Csg 6 -1/8" open hole MUD 11.9 ppg 10160' TD Proposed Well Schematic Prepared By CVK 7 -1 -09 . • Chevron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK AK 99519 -6247 %.1 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt @chevron.com July 1, 2009 RECEIVED A 0 2 2009 Commissioner 44iaska Oil & Gas Cons. Commission Alaska Oil & Gas Conservation Commission 4!icllofngrs 333 W. 7 Avenue Anchorage, Alaska 99501 Dear Commissioner, Perforated Tyonek zones for Stump Lake Unit 41 -33RD have not yielded any production. The well is currently shut in after producing roughly 48 bbl of diesel and water over several days. We have determined that these zones are producing water "The forward plan (see attached sundry) is to abandon the Tyonek zones and perforate a Beluga sand in an attempt to bring the well on production. For the proposed operations of plugging back the Tyonek zone in SLU 41 -33RD, we request a variance to AOGCC Regulation 20AAC25.112(I): The Beluga zone to be perforated has an expected formation pressure of 2,980psi, less than the currently open Tyonek formation pressure of 4,300psi. Therefore, we propose to perform a negative test to satisfy our pressure testing requirements for the abandonment plug as outlined in the attached procedure. As the well has not yet produced and we are systematically moving up the wellbore, a Well Completion Report 10 -407 has not been submitted. As with the Sundry 309 -148 (the sundry submitted to identify the initial perforations for this well), the attached sundry form 10 -403 (for isolating the Tyonek interval, and perforating in the Beluga) will also be closed out with the filing of the Well Completion Report 10 -407. If you have any questions or would like to discuss this matter, please do not hesitate to contact Chris Kanyer at 263 -7831. Sincerely, pp Timothy C. Brandenburg Drilling Manager Attachments: 10 -403 for Stump Lake Unit 41 -33RD Union Oil Company of California / A Chevron Company ° • • S rE o[F r SARAH PALIN, GOVERNOR ALASKA OIL AND GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION / ANCHORAGE, ALASKA 99501 -3539 CONSERVATION (907) 279 -1433 t FAX (907) 276 -7542 Timothy Brandenburg Drilling Manager Unocal PO Box 196247 Anchorage AK 99519 Re: Stump Lake Unit, Undefined Gas, SLU 41 -33RD Sundry Number: 309 -148 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this zr day of April, 2009 Encl. (C/1 ' � STATE OF ALASKA -1 APR 2 3 2009 ALAS IL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAILISska Oil & Gas Cons. Commission 20 AAC 25.280 Anchorage 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutdown ❑ Perforate ❑ Waiver ❑ Other ❑ Alter casing Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Change approved program Pull Tubing ❑ Perforate New Pool Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development Ei - Exploratory ❑ 209 -010 3. Address: Stratigraphic ❑ Service 0 6. API Number: PO Box 196247, Anchorage, Alaska, 99519 50- 283 - 20055 -01 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No IO Stump Lake Unit (SLU) 41 -33RD 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ADL- 058790 [Stup Lake Unit] • 45.1' MSL ` Stump Lake Unit, Undefined Gas 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,160 9,537 9,093 8,470 N/A N/A Casing Length Size MD TVD Burst Collapse Structural 77' 30" 77' 77' N/A N/A Conductor 424' 20" 424' 424' 1,530 psi 520 psi Surface 2,512' 13 -3/8" 2,512' 2,512' 5,380 psi 2,670 psi Intermediate 2,884' 9 -5/8" 2,884' 2,884' 6,330 psi 3,810 psi Production 6,120' 7- 5/8 "x7" 6,120' 5,506' 6,890 psi 4,790 psi Liner 4,125' 3 -1/2" 9,128' 8,505' 10,160 psi 10,530 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 3 -1/2" LS; 1.660" HS L -80; L -80 5003' LS; 2986' HS Packers and SSSV Type: Packers and SSSV MD (ft): Baker ZXP Liner Top Packer 5003' 13. Attachments: Description Summary of Proposal 151 14. Well Class after proposed work: Detailed Operations Program ❑ . BOP Sketch ❑ Exploratory ❑ Development El • Service ❑ 15. Estimated Date for 5/1/2009 16. Well Status after proposed work: Commencing Operations: Oil ❑ Gas El - Plugged ❑ Abandoned ❑ 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer 263 -7831 Printed Name e Timothy C. Brandenburg Title Drilling Manager Signature ). Phone 276 -7600 Date 4/23/2009 �J � COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,309-/- Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: \� • Cs��c CA � \i •-hR 4 `" 4 .- --- G�� C W r -c3 A1�� ' �s Subsequent Form Required: APPROVED BY f ZS Approved by: COMMISSIONER THE COMMON Date: JA L t i &s If f disco l `-/ Form 10-403 Revised 06/2006 Submit in lid j p • Chevron • Stump Lake Unit %101 Well # SLU 41 -33RD 4/23/09 OBJECTIVE: • Perforate Tyonek zone. PROCEDURE SUMMARY: 1 RU slickline. Pressure test lubricator 250psi low /2,500psi high. 2 RIH w/ GR and tag top of cement on BP at 9,033' RKB ( + / -). 3 RIH w/ 2 -1/2" x 20' dummy gun and tag cement at 9,033' RKB ( +f). 4 RD slickline. 5 RU Eline. Pressure test lubricator 250psi low /2,500psi high. 6 RIH and perf Tyonek sands from 8,872' RKB ( + / -) to 8,892' RKB ( + / -). 7 RD Eline. 8 Turn well over to production. Note: Swabbing contingency proposed on Sundry Number 309116 cancelled. SLU 41 -33RD REVISED BY: CVK 4/23/09 Chevron Stump 41 -33RD Permit to Drill #: 209 -010 itir• Lake Unit Lease & Serial #: ADL- 058790 ORIGINAL RIG Field: I Stump Lake Unit API# 50- 283 - 20055 -01 ELEVATIONS Surface Location: Well Classification Development Gas Well 773' FNL & 495' FEL Total Depth: 10,160' Sec 33,T14N,R8W,SM PBTD 9,033' RKB -GL T X: ASP4 375,758 Tubing (LS) 3 -W, 9.2 #, L -80, TC -II 16.80' J Y: ASP4 2,655,295 Tubing (Heater) 1.660 ", 3.02 9, L -80, BTS -8 RKB -MSL — - Well Status. Suspended Prod Pkrs: (1) 7" Baker "ZXP" Liner Top Pkr 45.10' I. Operator UOCC Ownership: Union Oil Company of California 100% GL -MSL: 28.30' Spud Date 2/23/09 1:00 PM RKB -MSL. 45.10' Other. Spud Feb 2009; Rig Release Mar 2009; SL Mar 2009; E -line Apr 77' Csg BHP: 4265 psi @ 10,160' MD 2009 BHT: 133° @ 10,160' MD CASING i Tubing • Rotate 424' Cog AI 46. Description Weight Grade Conn ID Length Top Btm TOC Hrs 46T Bowl Structural 30" N/A N/A Weld NA 77' 0' 77' Driven 32.0 hrs Surface 20" 94.0# H -40 BTC 19 124" 424' 0' 424' Surf 77.5 hrs Intermediate 13 3/8" 72.09 N -80 BTC 12.347" 2,512' 0' 2,512' Surf 240.8 hrs Intermediate 9 5/8" 43.59 N -80 BTC 8 755" 2,884' 0' 2,884' Surf 5so.5 hrs 2,512' Csg A 6,. Production 7 -5/8" 29.7# L -80 BTC -Mod 6.875" 123' 0' 123' - 180.0 hrs Production 7" 26.09 L -80 BTC -Mod 6.276" 5,99T 123' 6,120' 2,196' 180.0 hrs Liner 31/2" 9.2# L -80 IBT -Mod 2.992" 4,125' 5,003' 9,128' 5,003' 0.0 hrs 2,884' Csg 2,196' CaIcTOC 4 Tubing 31/2" 9.2# L -80 TC -11 2.992" 5,003' 0' 5,003' 15.8 ppg 412 sx - r{ Heat string 1 660" 3.029 L -80 BTS -8 1 278" 2,986' 0' 2,986' '1 Jewelry & Fish Description Depth Length ID OD 5,003' TOL 1 Tubing Hanger, Dual FTC- D- DFF6H, 3 -1/2" MCA, 1.900" IJ Lift Threads 17.5' 0.97' - - 1: ■:X 2 7" Baker ZXP packer (set 3/18/09) 5,003' 14.81' 5.250" 6.000" I -. — 3 7 "x5" Baker Flex -Lock III liner hanger (set 3/18/09) 5,018' 7.30' 5.250" 5.910" { 4 4 Baker Model 80 -40 Sealbore w/ GBH -22 Seal Assembly 5,025' 8.45' 4 000" 5.000" 5 Bridge Plug w/ 25' cement dump bailed (set 4/5/09) 9,033' 27.87' - - - 6 PBTD - Top of 3 -1/2" Float equipment (tag 3/25/09) 9,093' - - - 5,810' TOC (CBL) 12.5 ppg 450 sx ' 6,120' Csg 5,937' 10' Pup Jt 6,718' 10' Pup Jt Zone Top Btm And Gun Size SPF Phase Status Date 7,562' 10' Pup Jt Beluga /Tyonek None 8,406' 10' Pup Jt 8,950' BOC (CBL) 6% KCL 8.6 ppg 9,128' Csg 6 -1/8" open hole MUD 11.9 ppg 10160' TD Current Sketch Post E -line on 4/5/09 Prepared By Stan Porhola ____ . Chevron - 41'ROPOSED Permit to Drill #: 209 -0 0 SLU 41 -33RD Stump Lake Unit Lease & Serial #: ADL- 058790 ORIGINAL RIG Field: I Stump Lake Unit API #. 50- 283- 20055 -01 ELEVATIONS Surface Location Well Classification: Development Gas Well 773' FNL & 495' FEL Total Depth: 10,160' Sec 33,T14N,R8W,SM PBTD 9,033' RKB -GL X: ASP4 375,758 Tubing (LS): 3 -Y ", 9.2 #, L -80, TC -ll TT Y. ASP4 2,655,295 Tubing (Heater): 1.660 ", 3.02 #, L -80, BTS -8 RKB -MSL - - Well Status. Suspended Prod Pkrs: (1) 7" Baker "ZXP" Liner Top Pkr 45.10' Operator : UOCC Ownership: Union Oil Company of California 100 . 4 , GL -MSL: 28 Spud Date 2/23/09 1:00 PM RKB -MSL: 45.10' Other: Spud Feb 2009, Rig Release Mar 2009, SL Mar 2009; E -line Apr 77' Csg BHP: 4265 psi @ 10,160' MD 2009 BHT 133° @ 10,160' MD CASING & Tubing Rotate 424' Csg Description Weight Grade Conn ID Length Top Btm TOC Hrs 467' Bowl I I Structural 30" N/A N/A Weld NA 77' 0' 77' Driven 32.0 hrs Surface 20" 94.0# H -40 BTC 19 124" 424' 0' 424' Surf 77.5 hrs Intermediate 13 3/8" 72.0# N -80 BTC 12.347" 2,512' 0' 2,512' Surf 240.8 hrs Intermediate 9 5/8" 43.5# N -80 BTC 8 755" 2,884' 0' 2,884' Surf 560.5 hrs 2,512' Csg A ` Production 7 -5/8" 29.7# L -80 BTC -Mod 6.875" 123' 0' 123' - 140.0 hrs Production 7" 26.0# L -80 BTC -Mod 6.276" 5,997' 123' 6,120' 2,196' 180.0 hrs A. * Liner 3 1/2" 9.2# L -80 IBT -Mod 2 992" 4,125' 5,003' 9,128' 5,003' 0.0 hrs 2,884' Csg 2,196' Cale TOC ' Tubing 3 1/2" 9.2# L -80 TC -II 2.992" 5,003' 0' 5,003' 15.8 ppg 412 sx Heat string 1 660" 3.02# L -80 BTS -8 1 278" 2,986' 0' 2,986' Jewelry 8 Fish Description Depth Length ID OD 5,003' TOL " '' 'w'" A* © 1 Tubing Hanger, Dual FTC- D- DFF6H, 3 -1/2" MCA, 1.900" IJ Lift Thread. 17.5' 0.97' - - i . a is wi 2 7" Baker ZXP packer (set 3/18/09) 5,003' 14.81' 5.250" 6.000" it ti -, © 3 7 "x5" Baker Flex -Lock III liner hanger (set 3/18/09) 5,018' 7.30' 5.250" 5.910" 2 4 Baker Model 80 -40 Sealbore w/ GBH -22 Seal Assembly 5,025' 8.45' 4.000" 5.000" ! 5 Bndge Plug w/ 25' cement dump bailed (set 4/5/09) 9,033' 27.87' - - 6 PBTD - Top of 3 -1/2" Float equipment (tag 3/25/09) 9,093' - - - 5,810' TOC (CBL) } 12.5 ppg 450 sx 6,120' Csg • 5,937' 10' Pup Jt 6,718' 10' Pup Jt Perforations Zone I Top I Btm I Amt I Gun Size I SPF I Phase (Status I Date 7,562' 10' Pup Jt , ' . 1 Beluga/Tyonek Tyonek +.872'( + / -) 8,892'( + /_1 20' 2.5" 6 60 deg 'ROPOSED 8,406' 10' Pup Jt . , , 4 j 8,950' BOC (CBL) U : r ki j 12 6% KCL I tl 8.6 PP9 9,128' Csg 6 -1/8" open hole MUD 11.9 ppg 10160' TD Proposed Well Schematic Prepared By. _CVK 4 -23 -09 • • Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant. 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 %101 Tele: 907 263 7844 Fax: 907 263 7828 E -mail: fcbn @chevron.com DATE April 23, 2009 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste# 100 Anchorage, AK 99501 DATA TRANSMITTAL iA`Ea� ; .r,,,.. a 3 . r ..4TES_ :dap r. WE ^ ^ :;_'. : .� L © .':r;..:., ,._;....,.,.:�:r `. °•. � CALE''.;.;� ;� N' #• : �LINE ..d :. -� PDS, LAS, IRU 11 -06 USIT 5' 08- Feb -09 5900' -9900' 1 1 1 DLIS SLU 41- LWD GR DEPTH SHIFT PDS, LAS, 33RD QC PLOT 2' 20- Apr -09 5414' -9038' 1 1 1 DLIS 15--ltg 1190 11,0 i -010 Please acknowle , receipt by signing and - turning one copy of this transmittal or FAX to 907 263 7828. Received 8 :.s\ [ Date: 3 i i 'ievron Francisco Castro Chevron North America Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 °WO Tele: 907 263 7844 Fax: 907 263 7828 E -mail: fcbn @chevron.com DATE April 16, 2009 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste #100 Anchorage, AK 99501 DATA TRANSMITTAL - •''' ' n' `' ; ys � < , F..�: u :.�,t* - ice' °:r3`= - 6'� �; � . � �3 :, t = .L�•: h: ,.T. a� ,.""�'. .�.:� 9:; ,�tx °..p . hix;�;,o- .r- :.•, },. 9'�� . ioc. +dd,, - 9:a.,m /��: . r.�.`a �L:"n �A A sv ~r� ,t +r u } t . LY d;i s =S R�A " � • �.�E ' , D ° .;� � .m DOC, SLU 41 -33RD SURVEY REPORT 12- Mar -09 0'- 10160' 1 TXT, XLS CBL ABC -DELTA T PDS, LAS, SLU 41 -33RD GR -CCL 5' 04- Apr -09 5000' -9045' 1 1 1 DLIS MD LOG RECORDED 24- Feb -09 - SLU 41 -33RD MODE 2' 12- Mar -09 2855'- 10160' 1 -3 1 1 PDS, FMA TVD LOG RECORDED 24- Feb -09 - SLU 41 -33RD MODE 2' 12- Mar -09 2855'- 10160' 1 -3 1 1 PDS, FMA C - ;36.6. 1 Please acknowledge rece'i'pt by signing and returning one copy of this transmittal or FAX, to 907 263 7828, Received By: / ; /'. j Date: • • Chevron Francisco Cas'.1° Chevron North America Exploration and Production Technical Assn 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 %W. Tele: 907 263 7844 Fax: 907 263 7828 E -mail: fcbn @chevron.com DATE April 9, 2009 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste# 100 Anchorage, AK 99501 DATA TRANSMITTAL *aet. T A�. El2` N A'LE>: DA Rtl :'4VELC` r > - 0/jr!;:: ,�.= PDF, DML, FINAL WELL LAS, DOC, SLU 41 -33RD MUDLOGGING DATA 2" 12- Mar -09 2900'- 10160' 1 1 1 TIFF Doi - ora Please acknowledge rec�ipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: �.) % Date: • [F AL d.Y ( - ") { ArIE SARAH PALM, GOVERNOR ALASKA OIL AND GAS 333 W 7th AVENUE, SUITE 100 CONSERVATION COMMISSION / ANCHORAGE, ALASKA 99501 -3539 f PHONE (907) 279 -1433 FAX (907) 276 -7542 Tim Brandenburg Drilling Manager Unocal PO Box 196247 Anchorage AK 99519 Re: Stump Lake Unit, Undefined Gas, SLU 41 -33RD Sundry Number: 309 -116 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 4 Daniel T. Seamount, Jr. Chair DATED this day of April, 2009 End. ©� • • Chevron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, , AK AK 99519 -6247 Tel m a 7657 Email brandenburgt@chevron.com March 31, 2009 " Tom Maunder Alaska Oil & Gas Conservation Commission y 4/009 333 W. 7 Avenue 8 s Cans, Anchorage, Alaska 99501 Jnch C d ord q6 Re: Sundry Notice 10 -403, thru - tubing plugback and swabbing Stump Lake Unit, SLU 41 -33RD, PTD 209 -010 Mr. Maunder: Enclosed for your approval is a Sundry Notice (form 10 -403) for the proposed plugback and swabbing of the Stump ' Lake Unit SLU 41 -33RD Gas Development Well. During the liner cement job of the 3 -1/2" liner, a total of 152 bbl of cement was pumped and the shoetrack (0.25 bbl) volume was over - displaced (displaced w/ 6% KCL) in an attempt to bump the plug. The plug did not bump after 4 bbls and displacement was ceased in order to minimize further displacement of the cement from the shoe. The cement job maintained full returns throughout the job and a volume of +/- 62 bbl of cement was circulated off the top of the liner. The floats held and no pressure was observed in the well. The completion was ran without pressure testing the liner, the tree installed and the rig moved off location. Calculations show that this volume of cement is what would be recovered after circulating above the liner top. We expect cement behind the 3 -1/2" liner to be at 8958' RKB to the liner top at 5003' RKB. With the rig off location, we tested the tubing and liner to 4000 psi for 30 min and lost 105 psi (2.6 %). Slickline was run in the well. Initially, we tagged up at 8749' RKB (344' above landing collar). We worked down to 9093' RKB (top of landing collar). We recovered some fine sand, waxy fluid, Teflon debris from the wiper plug, and pieces of brass shear screws from the liner hanger while working down back to 9093' RKB. We followed up w/ a 2.84" gauge ring and 2.5" dummy gun runs that tagged up at 9039' RKB. The tubing and liner was tested again to 4000 psi for 30 min and lost 125 psi (3.1 %). No pressure or flow has been noted during these operations. Our proposed operation is to run a Sonic /Cement Bond log, isolate the shoe track w/ a bridge plug and dump bail 25' of cement. After isolating, RIH and tag the plugback depth, and swab the well down prior to perforating (separate sundry to follow). The proposed start date is April 2 Therefore, your earliest attention to this application will be greatly appreciated. If additional information is required, please contact either myself or Mr. Stan Porhola at 263 -7640. Sincerely, Timoth . andenburg Drilling Manager TCB: stp Attachments: Sundry Program Cc: Well File Engineer File — Stan Porhola Environmental — Megan Lewis Union Oil Company of California / A Chevron Company http: / /www.chevron.com OCI • STATE OF ALASKA • RECEIVED � i I) ,\/ • ALASKA OIL AND GAS CONSERVATION COMMISSION 1 14 ' , �` APPLICATION FOR SUNDRY APPROVALS Z yti MAR 3 1 ZOOS 20 AAC 25.280 1. Type of Request: Abandon❑ Suspend ❑ Operational shutdown ❑ Perforate CI 8 tf 8 ®f as 0 th r ISSIO Alter casing❑ Repair well El Plug Perforations ❑ Stimulate ❑ Time Extension El Anchorage Change approved program❑ Pull Tubing ❑ Perforate New Pool ❑ Re -enter Suspended Well El Ov 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: CJ�� Union Oil Company of California Development El • Exploratory ❑ 209 -010 " e1,41 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, Alaska, 99519 50- 283 - 20055- 01 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 11 SLU 41 -33RD 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL- 058790 • 45.1' MSL Stump Lake Unit, Undefined Gas 12 . PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 10,160 9537 9093 8470 N/A N/A Casing Length Size MD TVD Burst Collapse Structural 77 30" 77 77 N/A N/A Conductor 424 20" 424 424 1530 520 Surface 2512 13-3/8" 2512 2512 5380 2670 Intermediate 2884 9 -5/8" 2884 2884 6330 3810 Production 6120 7- 5/8 "x7" 6120 5506 6890 4790 Liner 4125 3 -1/2" 9128 8505 10160 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 3 -1/2" LS; 1.660" HS L -80; L -80 5003' LS; 2986' HS Packers and SSSV Type: Baker ZXP Liner Top Packer Packers and SSSV MD (ft): 5003' 13. Attachments: Description Summary of Proposal El 14. Well Class after proposed work: Detailed Operations Program El BOP Sketch El Exploratory ❑ Development 0 ' Service El 15. Estimated Date for 4/2/2009 16. Well Status after proposed work: Commencing Operations: Oil ❑ Gas 0 , Plugged ❑ Abandoned ' ❑ 17. Verbal Approval: Date: 3/31/2009 WAG ❑ GINJ ❑ WINJ El WDSPL ❑ Commission Representative: Tom Maunder / Cathy Foerster j- -t7µ 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Printed Name Tim Brandenburg Title Drilling Manager Signature hone 263 -7657 Date `� s 3/31/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: c3o9 - I / to Plug Integrity El BOP Test El Mechanical Integrity Test ❑ Location Clearance El Other: Subsequent Form Required: (Np1\CC 0.A -\\ kk E 0� �� c pQ k1/4� Ji r ` APPROVED BY q Approved by: COMMISSIONER THE COMMISSION Date: [ J 1n Form 10 -403 Revised 06/2006 1 i \ .. Rooms Fk_ APR 0 6 2009 Submit in a #/e Chevron 4 lump Lake Unit SLU 41 -33RD Plugback/Swab Revision #0 03/31/09 OBJECTIVE: • 1.) Plugback the shoe track. • 2.) Swab well down to achieve 20% underbalance prior to perforating. PROCEDURE SUMMARY: E -LINE OPERATIONS 1. Prep location for mobilizing E -line unit. 2. R/U E -line and test lubricator to 250/4000 psi. 3. RIH and log 3 -1/2" liner w/ Sonic logging tool. Collect Sonic and CBL data. POOH. 4. RIH and set bridge plug at +/- 9050' RKB in 3 -1/2" liner. POOH w/ setting tool. 5. RIH and dump bail 25' (0.2175 bbl) of 15.8 ppg cement on top of bridge plug. POOH w/ dump bailer. 6. R/D E -line and demobilize E -line unit. 7. Shutdown operations. SLICKLINE OPERATIONS 1. R/U Slickline and test lubricator to 250/1500 psi. 2. RIH and tag cement top at +/- 9025' RKB. POOH. CONTINGENCY: If cement top not at 9025' RKB, re- mobilize E -line and dump bail additional cement. 3. RIH w/ swab cups and swab top 1000' of fluid in well to achieve 20% underbalance. 4. R/D slickline and demobilize slickline unit. 5. Shutdown operations. * * *Separate 10 -403 sundry to follow for proposed perforating* * * V • 3 SLU 41 -33RD Plugback Procedure rev0.doc REVISED BY: STP 03/31/09 • • Chevron Well Name: SLU 41 -33RD ...410 Field: Stump Lake Unit %. Completion: Actual 3 -25 -09 All depths corrected to new RKB New rig RKB = 5.73' + Old rig RKB New Surface Location: L. J I Conductor: 30 ", to 83' Stump Lake Pad RKB 16.8' Above GL Surface Casing: I GL 28.30' Above MSL 20 ", 94 ppf, H -40, BTC to 430' X: 375,758 Y: 2,655,295 Sec. 33, T14N, R8W, SM Old Surface Location: RKB 14.0' Above GL Intermediate Casing: GL 25.37' Above MSL , k 13%", 72 ppf, N -80, BTC to 2518' X: 375,769 Y: 2,655,292 A- Intermediate Casing: (WINDOW) 8 1/2" Hole 9% ", 43.5 ppf, P -110, BTC to 2884' Intermediate Casing Cement Intermediate Casing: 15.8 ppg Lead cmt from 2196' - 6120' x 7 -5/8 ", 29.7 ppf, L -80, Hydril 521 from 0 to 123' 95 bbl (full returns, no cmt to surface) 7 ", 26 ppf, L -80, BTC -Mod from 123' to 6120' 5 4 ■ Fracture Gradients: 6 -1/8" Hole 1 Shoe @ 2884' MD (2884' TVD) = 11.0 ppg (LOT) Shoe @ 6120' MD (5506' TVD) = 15.0 ppg (FIT) Production Liner Casing Cement TD @ 10,160' MD (9537' TVD) = 14.4 ppg (Est.) 12.5 ppg Lead cmt from 5003' - 9,128' ` 152 bbl (full returns, circulate out 62 bbl above liner) over - displace by 4 bbl w/ 6% KCL BOC (Calc) / 8958' RKB Production Tubing: — r/ 6% KCL 3'/z', 9.2 ppf, L -80, TC -II to 5,003' ilti:\ 4 8.6 ppg Heater String Tubing: 1.660 ", 3.02 ppf, L -80, BTS -8 to 2986' MUD Production Liner. pp - 5009' Fluted Locator Assembly 11.9 1 Completion: 3%", 9.2 ppf, L -80, IBT -Mod liner from 5003' - 9,128' - 5030' GBH -22 Seal Assembly IBT -Mod (2.86') -• 7" 2.86') 7" x 5" Rotatable FlexLock liner hanger w/ ZXP Packer & Tieback sleeve at 5003' Seal bore extension (8.45') at 5025' to 5034' PBTD = 9,093' MD TD = 10,160' MD 4 WBD SLU 41 -33RD Actual 3- 25- 09.xls Mar 31, 2009 Drawn by: STP SLU 41 -33RD (PTD 209- 010)0er Review Page 1 off5___ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, March 31, 2009 10:58 AM To: 'PORHOLA, STAN T' Subject: RE: SLU 41 -33RD (PTD 209 -010) Liner Review Stan, Thanks for the update. I will look forward to the sundry. There is not an issue with conducting the logging operations. Isolating the shoe track with a bridge plug and cement is appropriate. I have advised Commissioner Foerster of your plans And she has given her oral approval for you to proceed. I would expect that we will have the sundry returned in advance of perforating. Call or message with any questions. Tom Maunder, PE AOGCC From: PORHOLA, STAN T [ mailto :stan.porhola ©chevron.com] Sent: Tuesday, March 31, 2009 10:40 AM To: Maunder, Thomas E (DOA) Subject: SLU 41 -33RD (PTD 209 -010) Liner Review During the liner cement job of the 3 -1/2" liner, a total of 152 bbl of cement was pumped and the shoetrack (0.25 bbl) volume was over - displaced (displaced w/ 6% KCL) in an attempt to bump the plug. The plug did not bump after 4 bbls and displacement was ceased in order to minimize further displacement of the cement from the shoe. The cement job maintained full returns throughout the job and a volume of +/- 62 bbl of cement was circulated off the top of the liner. The floats held and no pressure was observed in the well. The completion was ran without pressure testing the liner, the tree installed and the rig moved off location. Calculations show that this volume of cement is what would be recovered after circulating above the liner top. We expect cement behind the 3 -1/2" liner to be at 8958' RKB to the liner top at 5003' RKB. With the rig off location, we tested the tubing and liner to 4000 psi for 30 min and lost 105 psi (2.6 %). Slickline was run in the well. Initially, we tagged up at 8749' RKB (344' above landing collar). We worked down to 9093' RKB (top of landing collar). We recovered some fine sand, waxy fluid, Teflon debris from the wiper plug, and pieces of brass shear screws from the liner hanger while working down back to 9093' RKB. We followed up w/ a 2.84" gauge ring and 2.5" dummy gun runs that tagged up at 9039' RKB. The tubing and liner was tested again to 4000 psi for 30 min and lost 125 psi (3.1 %). No pressure or flow has been noted during these operations. Our proposed operation is to run a Sonic /Cement Bond log, isolate the shoe track w/ a bridge plug and dump bail 25' of cement. After isolating, RIH and tag the plugback depth, and swab the well down prior to perforating (separate sundry to follow). The proposed start date is April 2nd Attached is an updated schematic. «WBD SLU 41 -33RD Actual 3- 25- 09.xls» Stan Porhola•• Drilling Engineer MidContinent /Alaska Business Unit 3/31/2009 • • Chevron Well Name: SLU 41 -33RD t Field: Stump Lake Unit 410 All depths corrected to new RKB Completion: Actual 3 -25 -09 New rig RKB = 5.73' + Old rig RKB New Surface Location: L J Conductor: 30 ", to 83' Stump Lake Pad RKB 16.8' Above GL Surface Casing: GL 28.30' Above MSL 20 ", 94 ppf, H -40, BTC to 430' X: 375,758 Y: 2,655,295 Sec. 33, T14N, R8W, SM Old Surface Location: RKB 14.0' Above GL Intermediate Casing: GL 25.37' Above MSL 13%", 72 ppf, N-80, BTC to 2518' X:375,769 Y: 2,655,292 Intermediate Casing: (WINDOW) 8-1/2" Hole I 9 % ", 43.5 ppf, P -110, BTC to 2884' Intermediate Casing Cement: Intermediate Casing: 15.8 ppg Lead cmt from 2196' - 6120' X 7 -5/8 ", 29.7 ppf, L -80, Hydril 521 from 0 to 123' 95 bbl (full returns, no cmt to surface) 7 ", 26 ppf, L -80, BTC -Mod from 123' to 6120' Fracture Gradients: 6 -1/8" Hole I Shoe @ 2884' MD (2884' TVD) = 11.0 ppg (LOT) Shoe @ 6120' MD (5506' TVD) = 15.0 ppg (FIT) Production Liner Casing Cement: TD @ 10,160' MD (9537' TVD) = 14.4 ppg (Est.) 12.5 ppg Lead cmt from 5003' - 9,128' 152 bbl (full returns, circulate out 62 bbl above liner) over - displace by 4 bbl w/ 6% KCL BOC (Calc) 8940' RKB Production Tubing: 6% 3%", 9.2 ppf, L -80, TC -II to 5,003' 6/o KCL ��!• 41--- 8.6 ppg Heater String Tubing: 1.660 ", 3.02 ppf, L -80, BTS -8 to 2986' MUD Completion: Production Liner: - 5009' Fluted Locator Assembly P 3W, 9.2 ppf, L -80, IBT -Mod liner from 5003' - 9,128' - 5030' GBH -22 Seal Assembly IBT -Mod (2.86') 7" x 5" Rotatable FlexLock liner hanger w/ ZXP Packer & Tieback sleeve at 5003' Seal bore extension (8.45') at 5025' to 5034' PBTD = 9,093' MD TD = 10,160' MD WBD SLU 41 -33RD Actual 3- 25- 09.xls Mar 25, 2009 Drawn by: STP SLU 41 -33RD - 3.5" liner set sipow • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) a®` _ 0 ∎ 0 Sent: Wednesday, March 18, 2009 1:55 PM �.J To: 'Bonnett, Nigel (Nigel.Bonnett)' Cc: Brandenburg, Tim C; PORHOLA, STAN T Subject: RE: SLU 41 -33RD - 3.5" liner set shallow Nigel, et al, Thanks for the summary and the daylight hours call. I understand the difficulties that can be encountered with wells in Cook Inlet. It is unfortunate that both equipment and hole problems were combined. While engagement is always appreciated, sharing your pain late at night is not always necessary. In this case, hole conditions pretty well forced your decision. I am not sure I could have contributed to the discussion and would not have 2nd guessed you on the decision. It is possible that had this been an OH plugging decision, then a late night call likely would have been more appropriate. Since you have not indicated difficulties were encountered cementing the casing, it is likely that isolation at the shoe has been obtained which will confine the 90 -9 sand. Call or message with any questions. I will place a copy of this message in the well file. Tom Maunder, PE AOGCC From: Bonnett, Nigel (Nigel.Bonnett) [ mailto :Nigel.Bonnett@chevron.com] Sent: Wednesday, March 18, 2009 1:15 PM To: Maunder, Thomas E (DOA) Cc: Brandenburg, Tim C; PORHOLA, STAN T Subject: SLU 41 -33RD - 3.5" liner set shallow Tom, Last night at 10:30 p.m., we were unable to make further progress in the hole. We had reached 9,130 ft MD, with a planned setting depth of 10,000 ft MD. We spent 3 hours at this depth trying to work through. We were in a sand interval and these had not been problematic in running the liner - we had been required to work the liner through coal intervals above. Subsequently it appears that there is a fault prognosed within 20 ft and this (differential hole enlargement at the fault) may have been the cause of hold up. During the liner run we had experienced two Top Drive malfunctions. The first we were able to pull to the shoe and rectify; the second resulted in working pipe in open hole for 4 hours (as unable to break pipe), while determining remedy. With the 3.5" liner shoe at 9,130 ft MD, the Tyonek sands remained uncaptured The Asset Development Team had assessed that there was only one Tyonek sand of interest - the 38 ft Tyonek 90 -9 sand interval with resistivity of 9 ohm had a 60% POS. The Tyonek sands were —40 ft lower than prognosed and evaluated to be wet apart from the 90 -9 Sand. On this basis the Asset Team requested we set and cement the liner at 9,130 ft MD to capture the Sterling and Beluga sands below the 7" casing shoe. Prior to running the liner, we had made two unsuccessful attempts at deploying wireline SP/ sonic logs, only getting to a depths of 6245 ft and 6410 ft, not far out of the 7" shoe at 6120 ft. We did perform a clean out trip after the first failed logging run, only seeing a slight bobble on the weight indicator at logging tool hold up depth. On circulating bottoms up at well TD, we saw larger (nickel sized) pieces of coal for the first time. As discussed this morning, we do realise that we should have engaged the AOGCC at the time, to get your concurrence, rather than executing the shallow liner set and subsequently discussing with you this morning. Obviously timing of the operations (midnight) was not very conducive to such dialogue. 3/18/2009 SLU 41 -33RD - 3.5" liner set sow • Page 2 of 2 Perhaps we should look to pro - actively discuss with you such events in the future, if we envisage (the challenge, no doubt) such issues manifesting outside office hours. Regards, Nigel Nigel Bonnett • • Drilling Engineering Manager MCA SBU - Alaska Chevron North America Exploration & Production 3800 Centerpoint Drive Suite 100 Anchorage, Alaska 99503 Telephone (direct) : (907) 263 7853 Mobile : (907) 350 6267 Facsimile : (907) 263 7884 E -mail: nigel.bonnett @chevron.com 3/18/2009 Cement Job Revision for SLU 03RD (PTD 209 -010) Page 1 of /k Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, March 18, 2009 10:03 AM To: 'PORHOLA, STAN T' Subject: RE: Cement Job Revision for SLU 41 -33RD (PTD 209 -010) Stan, It appears I did not respond to you about the cementing change. That may be somewhat moot now. The main issue is cementing the casing properly. While a lighter weight slurry was preferred, you have to use what you have on hand. I appreciate the information on the change. I will place a copy of this message in the file. Tom Maunder, PE AOGCC From: PORHOLA, STAN T [mailto:stan.porhola @chevron.com] Sent: Monday, March 16, 2009 5:03 PM To: Maunder, Thomas E (DOA) Subject: Cement Job Revision for SLU 41 -33RD (PTD 209 -010) Tom, In reviewing our well operations at Stump Lake SLU 41 -33RD, I was negligent in informing you of a change that was made to our planned cement job for our 7- 5/8 "x7" casing string. The approved permit had a 12.0 ppg pre - blended slurry (yield = 2.24 ft3 /sx). Due to logistical constraints, we did not have enough cement on location to pump the required job volume 95 bbl (plan was for 68 bbl). This volume was based on 40% open hole excess, but fluid calipers indicated that we needed 75% open hole excess. We ended up pumping a 15.8 ppg slurry (yield = 1.15 ft3 /sx) with the Class G cement plus additives we had available on the westside of Cook Inlet. We had full returns during the cement job (no losses). We did not bump the plug after displacing 233 bbls (232 bbl calculated). It was determined that the displacement volume was not counted properly and more than likely less than 233 bbl was pumped. When cleaning out the casing, cement was found 240' (5795' MD) above the float collar (6035' MD). This is approximately 18 bbls. For our upcoming cement job on our 3 -1/2" liner, we are planning to adjust our pre - blended 12.0 ppg slurry (extra slurry was shipped by L -382 Herc pods) to a 12.5 ppg slurry. This change will be affected by changing the mix water requirements from 9.70 gal /sx to 7.70 gal /sx. Lab tests show that this will not compromise the cement properties. We are doing this since our mud weight is currently 11.9 ppg (planned as high as 11.6 ppg). We've brought our mud weight up in an attempt to control coals stabilization issues in the well. We TD'd the well at 11.4 ppg. During our wiper trip, we increased to 11.6 ppg to shut -off gas that was entering the wellbore. We plan to commence cementing operations as early as Tuesday evening, Mar 17, 2009. If you have any questions, please feel free to contact. Stan Porhola• • Drilling Engineer MidContinent /Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Dr. Suite 100 3/18/2009 SLU 41 -33RD (PTD 209 -010) It-off Test of 9 -5/8" window Page 1 of 5 Maunder, Thomas E (DOA) From: Bonnett, Nigel (Nigel.Bonnett) [Nigel.Bonnett @chevron.com] Sent: Thursday, February 26, 2009 4:42 PM To: Maunder, Thomas E (DOA) Subject: RE: SLU 41 -33RD (PTD 209 -010) Update Tom, Just an update. We commenced drilling yesterday at 07:00 hrs. At midnight we had made 700 ft and were at 3706 ft. This morning at 07:30 we were at 4138 ft. Only issue we have seen is fault zone 3940 - 3950 ft, where we took 10K o /pull on conn. Original well we got stuck in this fault. Out of magnetic interference - it took longer than predicted - we gyro single shot. Mud weight 9.3 ppg. Directionally on plan. Hole cleaning good. Nigel From: Maunder, Thomas E (DOA) [mailto:tom.maunder©alaska.gov] Sent: Tuesday, February 24, 2009 4:22 PM To: Bonnett, Nigel ( Nigel.Bonnett) Cc: Harness, Evan; PORHOLA, STAN T; Grimaldi, Louis R (DOA) Subject: RE: SLU 41 -33RD (PTD 209 -010) Leak -off Test of 9 -5/8" window Nigel, et al, I acknowledge receiving your information and our discussions. Commissioner Foerster and I have also discussed this. 250 psi does appear to be the final point on the straight line, however there were only 2 points plotted. In our latest discussion you indicated that no finer increment in time or volume is available. The early part of the information does not look unusual. Point 6 and then the fall -off are not encouraging. Using the final observation point, -50 psi, gives 9.6 EMW. If the ECD increment over mud weight (0.5 ppg) at TD that Stan estimates is proportioned based on the relative tvds, then slightly less than 0.3 ppg should be added to the mud weight. If 9.5 ppg is used as Stan estimates, then the ECD at the window would be - 9.8 which exceeds the value calculated from the bleed off pressure. Regardless of the calculations, the tolerances are close. If the lithology is as stated, then the rapid fall -off could be due to it. You have drilled the window not far above the DV collar in the 9 -5/8" casing. Due to the proximity to the DV and the cement volume pumped through it, it is likely that there is cement isolation to well above the window. You have indicated that it is planned to incorporate some CaCO3 into the mud which could help seal /damage the more permeable formations that might be encountered. The section risk is somewhat mitigated since the wellbore above the abandonment plugs was successfully pressure tested (Inspector witnessed) and this section is an intermediate although as pointed out there are coals to be drilled. While drilling ahead, it is expected that you will be monitoring your fluid volumes and properties. If losses are encountered, the need to evaluate squeezing or employing greater LCM treatments is likely. Necessary material should be available if contingencies are needed. I request that you provide me with morning operational reports while this section is drilled. Call or message with any questions. Tom Maunder, PE AOGCC From: Bonnett, Nigel ( Nigel.Bonnett) [mailto:Nigel.Bonnett@chevron.com] Sent: Tuesday, February 24, 2009 10:49 AM To: Maunder, Thomas E (DOA) Cc: Harness, Evan; PORHOLA, STAN T; Grimaldi, Louis R (DOA) Subject: RE: SLU 41 -33RD (PTD 209 -010) Leak -off Test of 9 -5/8" window 3/31/2009 SLU 41 -33RD (PTD 209 -010) ,-offTest of 9 -5/8" window . Page 2 of 5 Tom, As we discussed this morning, I confirm that on Stump Lake Unit well 41 -31 RD, we attempted two FIT tests to 11.0 ppge (257 psi with 9.3 ppg mud at 2,884 ft TVD). With both these FIT tests, 0.5 bbl was pumped and pressure bled off fairly quickly. The BJ cement unit & surface lines were tested prior to the failed FIT's. At this point, it was decided to go to LOT mode and a total of 1.5 bbls were pumped. Based on the data sent yesterday, it does appear that a Leak Off at around 250 psi was achieved, which equates to 11.0 ppge. Again, on ceasing pumping, the pressure bled off quickly. A FIT of 11.0 ppg was originally planned for well 41 -33RD. The interval where we have kicked off is generally fairly silty /sandy throughout. There is no mud log data at this depth - only obtained from 3600 ft. The milling of the window went well and took 6 hours. The Chevron DSM and Mud Engineer did see indications of cement with the metal filings. The milled window location was specifically selected above the 9 -5/8" DV collar to assure presence of cemented casing. Based on the above, we see no reason to believe we have a cement integrity issue at the 9 -5/8" casing window. There was no apparent "break down" in pressure during the two attempted FIT's, prior to going to Leak Off mode. We believe the effects observed are solely a function of the window being in a silty interval. We therefore propose to proceed with drilling the 8 -1/2" hole interval as planned. Please advise if you concur. Thanks, Nigel From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, February 24, 2009 8:18 AM To: PORHOLA, STAN T; Grimaldi, Louis R (DOA) Cc: Harness, Evan; Bonnett, Nigel (Nigel.Bonnett) Subject: RE: SLU 41 -33RD (PTD 209 -010) Leak -off Test of 9 -5/8" window Stan, et al, Thanks for the fall -off data. The quick decline further indicates the limited integrity at the drilled depth. I would appreciate a call to hear Chevron's assessment of the information thus far developed. Tom Maunder, PE AOGCC From: PORHOLA, STAN T [mailto:stan.porhola @chevron.com] Sent: Monday, February 23, 2009 10:39 PM To: Maunder, Thomas E (DOA); Grimaldi, Louis R (DOA) Cc: Harness, Evan; Fowler, Don; Purugganan,Abraham; Bonnett, Nigel (Nigel.Bonnett) Subject: RE: SLU 41 -33RD (PTD 209 -010) Leak -off Test of 9 -5/8" window Tom and Lou, Attached are the revised LOT data w/ the "after pumps off' data included. This data was not included in the last submittal. Stan Porhola• • Drilling Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 3/31/2009 -'4 Stump Lake SLU 41 - 33RD 350 Pressure vs Volume ALASKA DRILLING 9 -5/8" Formation Integrity Test 2884' MD / 2884' TVD NW 300 • DATE: 2/23/2009 Strokes Volume Pump Time FOREMAN Fowler /Purugganan Pumped Pressure 250 FIELD: Stump Lake (BBLS) (psi) (min) PLATFORM: Onshore - 0 - WELL: SLU 41 -33RD 0.25 255 1.0 " g 200 0.50 294 2.0 SIZE: 9.625 IN 0.75 277 3.0 a 15o WEIGHT: 43.5 LBS 1.00 280 4.0 GRADE: L -80 1.25 288 5.0 BURST: 6,330 PSI 1.50 224 6.0 00 MAX. PRESS: 4,431 PSI 1.50 1 1 1 7.0 TEST PRESS: 2,000 PSI 1.50 69 8.0 50 • 1.50 48 9.0 CSG DEPTH (MD): 2,884 FT CSG DEPTH (TVD): 2,884 FT - 0 I - 0.20 0.40 0.60 080 100 120 140 1.80 TD (MEASURED): 2,904 FT - Volume (8131.$) TD (TVD): 2,904 FT - FLUID TYPE: WBM - MW: 9.30 PPG - Pressure vs Time INCREMENTS: 0.25 BBLS - PUMP IN RATE: 0.25 BPM - 350 LEAKOFF(GRAPH): 200 PSI - LOT OR FIT ?: LOT - 300 FRAC GRAD: 0.553 PSI/FT - EMW: 10.63 PPG - 250 I KB - MSL - FT - KB - MUD LINE FT ICOR FG.: 0.55 PSI /FT S 200 COR EMW: 10.63 PPG a 150 -- - 100 50 7 0 - 10 20 30 4.0 5.0 8.0 7.0 8.0 9.0 '0. Time (Minutes) Note: .done w/ cmt pump @ .25 bbl per min LOT SLU 41 -33RD 9 625 (Revised).xls 3/31/200911:15 AM SLU 41 -33RD (PTD 209 - 010) 10 -off Test of 9 -5/8" window Page 3 of 5 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tel 907 263 7640 Fax 907 263 7884 Cell 907 229 1769 stan.porhola @chevron.com illail Confidential Footer Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263 -7640. From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, February 23, 2009 10:25 PM To: PORHOLA, STAN T; Grimaldi, Louis R (DOA) Cc: Harness, Evan; Fowler, Don; Purugganan,Abraham; Bonnett, Nigel (Nigel.Bonnett) Subject: RE: SLU 41 -33RD (PTD 209 -010) Leak -off Test of 9 -5/8" window Stan, et al, Following up on our conversation. You indicated that the pressure bled off quickly after pumping was stopped after six strokes. The pressure fall -off behavior does not indicate great integrity. It may have been appropriate to have attemped a 2nd integrity test prior to pulling out of hole to see if the intiial pressure response could be replicated. It is my opinion that another leak off test should be attempted. AOGCC regulations allow the LOT /FIT to be conducted after drilling not less than 20' and no more than 50' of hole. I will be available on my cell through the night. Tom Maunder, PE AOGCC From: PORHOLA, STAN T [mailto:stan.porhola @chevron.com] Sent: Mon 2/23/2009 9:53 PM To: Maunder, Thomas E (DOA); Grimaldi, Louis R (DOA) Cc: Harness, Evan; Fowler, Don; Purugganan,Abraham; Bonnett, Nigel (Nigel.Bonnett) Subject: RE: SLU 41 -33RD (PTD 209 -010) Leak -off Test of 9 -5/8" window Tom and Lou, Attached is the spreadsheet for the LOT on Stump Lake SLU 41 -33RD (PTD 209 -010). We plan to drill the hole section w/ flow rates up to 585 gpm w/ 4" drillpipe. With our mud weight of 9.5 ppg and mud properties of PV = 9 and YP = 26 (same properties at Ivan River IRU 11 -06) , we should see a maximum ECD at 10.0 ppg at the bottom of the hole section at 6059' MD / 5443' TVD. ECD's at the window should be less than 10.0 ppg. However, we will need to re- evaluate our cement designs to make sure we will have an ECD at the shoe below 10.6 ppg. I will follow up on the cement design for our next casing string on this well. Stan Porhola• • 3/31/2009 SLU 41 -33RD (PTD 209 - 010)1 -off Test of 9 -5/8" window Page 4 of 5 Drilling Engineer MidContinent /Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tel 907 263 7640 Fax 907 263 7884 Cell 907 229 1769 stan.porhola @chevron.com mail Confidential Footer Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263 -7640. From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, February 23, 2009 9:40 PM To: PORHOLA, STAN T; Grimaldi, Louis R (DOA) Cc: Harness, Evan; Fowler, Don; Purugganan,Abraham Subject: RE: SLU 41 -33RD (PTD 209 -010) Leak -off Test of 9 -5/8" window Importance: High Gentlemen, Neither Lou or I have received the spreadsheet containing the leak -off test data. That would be appreciated as soon as possible. Also some description should be provided of the specifics of the planned 8 -1/2" hole section. You state that the intent is to TD the hole section with 9.5 ppg mud. Is it realistic that your mud weight will only increase 2/10 drilling the interval or that your ECD at the shoe /window will be less than about 1 ppg? We look forward to your reply. Tom Maunder, PE AOGCC From: PORHOLA, STAN T [mailto:stan.porhola @chevron.com] Sent: Mon 2/23/2009 7:47 PM To: Grimaldi, Louis R (DOA); Maunder, Thomas E (DOA) Cc: Harness, Evan; Fowler, Don; Purugganan,Abraham Subject: SLU 41 -33RD (PTD 209 -010) Leak -off Test of 9 -5 /8" window Lou and Tom, Our planned FIT of 11.0 ppg of our 9 -5/8" shoe at Stump Lake SLU 41 -33RD turned out to be a 10.6 ppg LOT w/ a 9.3 ppg mud at 2884' TVD. 3/31/2009 SLU 41 -33RD (PTD 209 -010) ist-off Test of 9 -5/8" window Page 5 of 5 The field will be sending a spreadsheet with the test data for the 10.6 LOT. Our PTD (209 -010) for SLU 41 -33RD assumed a 11.0 ppg frac gradient at our shoe, a kick intensity of 10.0 ppg and a kick volume of 10.0 bbl. We drilled this same geology to a depth below the Beluga coal (top of the Beluga coal at Ivan River is 4838' TVD, at Stump Lake it is at 5341' TVD) with a 9.5 ppg mud at Ivan River IRU 11 -06 back in January, which is approximately 2 miles to the southwest of the Stump Lake location. The 10 ppg kick intensity was a conservative estimate with a planned mud weight at TD between 9.1 - 10.0 ppg. Our forward plan is to drill ahead with using our planned mud weight schedule and TD the hole section with a 9.5 ppg mud weight, unless hole conditions dictate otherwise. Our expected pore pressures are 8.5 ppg. There are no disposal zones or any known geo- pressured zones in this hole interval, but it does contain several coal sections. The cuttings and offset data show the formation at our window is unconsolidated sands and gravels. We do not plan to squeeze our shoe since there is a low chance of success with the geology present. Attached are revised kick tolerance calcuations using the 10 ppg intensity (giving a 5.8 bbl kick tolerance) and a 9.5 ppg intensity (giving a 12.7 bbl kick tolerance). Please advise as to any additional requirements for making this change to our permit. «SLU 41 -33RD KT 5443TVD 7inch (5.8 bbl at 10 ppg).xls» «SLU 41 -33RD KT 5443TVD 7inch (12.7 bbl at 9.5 ppg).xls» Stan Porhola• • Drilling Engineer MidContinent /Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tel 907 263 7640 Fax 907 263 7884 Cell 907 229 1769 stan.porhola @chevron.com fail Confidential Footer Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part vet If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263 -7640. 3/31/2009 • • UINICHICAL GENERAL INPUT DATA Field Stump Lake Well Name 41 -33RD RT -MSL 16.8 ft Water Depth 0 ft Sea Water Gradient 0.447 psi /ft Casing Size to be Designed 7 inch Hole Size Drilled for This Casing 8 -1/2 inch DESIGN METHOD 1: From TD up to find the shallowest allowable shoe depth Hole Size Below the Shoe 6 -1/8 inch Next Section Total Vertical Depth 9,434 ft TVD RKB Next Section Total Vertical Depth 9,417 ft TVD BML Next Section Gas Gradient (first approximation: 0.089) 0.100 psi /ft Kick Intensity (Swab kick = 0.0 ppg intensity) 0.0 PPG Mud Weight 11.6 PPG Estimated Formation Pressure at Next Section TD 11.6 PPG EMW Fracture Gradient 0.68 psi /ft Kick Tolerance 10.0 bbl Drill Pipe Outside Diameter 4 inch Calculation results acceptable. Minimum shoe depth = 5,362 ft TVD RKB 1 DESIGN METHOD 2: From upper casing shoe down to find the deepest hole which can be drilled without fracturing the upper casing shoe Upper Casing Size 9 -5/8 inch Upper Casing Shoe Depth 2,884 ft TVD RKB Upper Casing Shoe Depth 2,867 ft TVD BML Upper Gas Gradient (first approximation: 0.021) 0.100 psi /ft Hole Size below the Upper Casing Shoe 8 -1/2 inch Kick Intensity (Swab kick = 0.0 ppg intensity) 0.0 PPG Mud Weight 9.5 PPG Estimated Formation Pressure 9.5 PPG EMW Fracture Gradient 0.55 psi /ft Kick Tolerance 12.7 bbl Drill Pipe Outside Diameter 4 inch Calculation results acceptable. Maximum shoe depth = 5,455 ft TVD RKB 1 mdb /03jan01 • • Stump Lake 41 -33RD UINIOCAL .*7f'43 7" SHOE DESIGN SUMMARY & SKETCH METHOD 2: METHOD 1: I RT- MSL =16.8ft 7—_______________-- I WD = 0 ft with 0.447 PSI /FT Gradient DESIGN DOWN: 9 -5/8" shoe MW = 10 PPG 2,867 ft BML Pform = 10 PPG EMW 9 -5/8" shoe, (2,884 ft TVD) \ KT = 5.8 BBLS at 0 PPG / FG = 0.5512 PSI /FT \ Gas Gradient = 0.1 PSI /FT / Drill Pipe = 4 INCH \ 8 -1/2" Hole / / The shallowest \ 7 " shoe depth = / 5,345 ft BML or 5,362 ft TVD ■ A / \ \ / / \ \ / / \ The deepest 8 -1/2 in hole \ that can be drilled = / 5,504 ft BML or 5,521 ft TVD \ - DESIGN UP: / MW = 11.6 PPG \ Pform = 11.6 PPG EMW 6 -1/8" Hole / KT = 10 BBLS at 0 PPG \ FG = 0.676 PSI /FT / Gas Gradient = 0.1 PSI /FT \ Drill Pipe = 4 INCH TD= 9,417 ft BML or 9,434 ft TVD / mdb /01 dec00 • • GENERAL INPUT DATA Field Stump Lake Well Name 41 -33RD RT -MSL 16.8 ft Water Depth 0 ft Sea Water Gradient 0.447 psi /ft Casing Size to be Designed 7 inch Hole Size Drilled for This Casing 8 -1/2 inch DESIGN METHOD 1: From TD up to find the shallowest allowable shoe depth Hole Size Below the Shoe 6 -1/8 inch Next Section Total Vertical Depth 9,434 ft TVD RKB Next Section Total Vertical Depth 9,417 ft TVD BML Next Section Gas Gradient (first approximation: 0.089) 0.100 psi /ft Kick Intensity (Swab kick = 0.0 ppg intensity) 0.0 PPG Mud Weight 11.6 PPG Estimated Formation Pressure at Next Section TD 11.6 PPG EMW Fracture Gradient 0.68 psi /ft Kick Tolerance 10.0 bbl Drill Pipe Outside Diameter 4 inch (Calculation results acceptable. Minimum shoe depth = 5,362 ft TVD RKB 1 DESIGN METHOD 2: From upper casing shoe down to find the deepest hole which can be drilled without fracturing the upper casing shoe Upper Casing Size 9 -5/8 inch Upper Casing Shoe Depth 2,884 ft TVD RKB Upper Casing Shoe Depth 2,867 ft TVD BML Upper Gas Gradient (first approximation: 0.022) 0.100 psi /ft Hole Size below the Upper Casing Shoe 8 -1/2 inch Kick Intensity (Swab kick = 0.0 ppg intensity) 0.0 PPG Mud Weight 10.0 PPG Estimated Formation Pressure 10.0 PPG EMW Fracture Gradient 0.55 psi /ft Kick Tolerance 5.8 bbl Drill Pipe Outside Diameter 4 inch Calculation results acceptable. Maximum shoe depth = 5,521 ft TVD RKB 1 mdb /03jan01 • 1 Stump Lake 41 -33RD UIPIOCAL 7" SHOE DESIGN SUMMARY & SKETCH METHOD 2: METHOD 1: — RT- MSL =16.8ft I WD = 0 ft with 0.447 PSI /FT Gradient DESIGN DOWN: 9 -5/8" shoe MW = 9.5 PPG 2,867 ft BML, Pform = 9.5 PPG EMW 9 -5/8" shoe, (2,884 ft TVD) \ KT = 12.7 BBLS at 0 PPG / FG = 0.5512 PSI /FT \ Gas Gradient = 0.1 PSI /FT / Drill Pipe = 4 INCH 8 -1/2" Hole / / The shallowest \ 7 " shoe depth = / 5,345 ft BML or 5,362 ft TVD \ 4 / \ ■ / / ■ \ / / \ The deepest 8 -1/2 in hole \ that can be drilled = / 5,438 ft BML or 5,455 ft TVD \ DESIGN UP: / MW = 11.6 PPG \ Pform = 11.6 PPG EMW 6 -1/8" Hole / KT = 10 BBLS at 0 PPG \ FG = 0.676 PSI /FT / Gas Gradient = 0.1 PSI /FT \ Drill Pipe = 4 INCH TD = 9,417 ft BML or 9,434 ft TVD / mdb /01 dec00 • 1 r 1 \ \ [LAsEA SARAH PALIN, GOVERNOR tJ ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM1'HSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Tim Brandenburg Drilling Manager Unocal PO Box 196247 Anchorage AK 99519 Re: Stump Lake Field, Stump Lake Unit Undefined Gas, SLU 41 -33RD Unocal Permit No: 209 -010 Surface Location: 772' FNL, 505' FEL, SEC. 33, T14N, R8W, SM Bottomhole Location: 559' FSL, 1645' FEL, SEC. 28, T14N, R8W, SM Dear Mr. Brandenburg: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). incerely, Daniel T. Seamount, Jr. 4 1- Chair DATED this ± day of February, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. RECEIVED STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMAKION JA \I 2 3 2009 PERMIT TO DRILL 4 Alaska Oil & Gas Cons. Commission 20 AAC 25.005 AA'' 1 a. Type of Work: lb. Current Well Class: Exploratory ❑ Development Oil ❑ lc. Specify if well is proposk 4urage Drill ❑ Redrill. Ei Stratigraphic Test ❑ Service ❑ Development Gas ' 0 Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone • 0 Shale Gas ❑ 2. Operator Name: 0 1/6749 5. Bond: Blanket 0 • Single Well ❑ 11. Well Name and Number: Cbeworr'(Qnion Oil Company of California) Bond No. 086S103515406 ism R y fdist SLU 41 -33RD • 3. Address: 6. Proposed Depth: 12. Field /Pool(s): PO Box 196247, Anchorage, Alaska, 99519 MD: 10060 ' TVD: 9437 Stump Lake Unit , 4a. Location of Well (Governmental Section): 7. Property Designation: Undefined Gas Surface: 772 FNL, 505' FEL, Sec 33, T14N, R8W, SM ADL- 058790 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 509 FSL, 1603' FEL, Sec 28, T14N, R8W, SM N/A 2/12/2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest 559 FSL, 1645' FEL, Sec 28, T14N, R8W, SM • 1105 Pr perty: „�Dor+' wee-W t gD /•i4.o•Y 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 16.80 AGL ' 6 Distance to Nearest Well Surface: x- 375,758 y- 2,655,295 Zone- ASP 4 (Height above GL): 45.10 AMSL • Within Pool: N/A 16. Deviated wells: Kickoff depth: 3000 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 48 degrees Downhole: 4494 Surface: 3677 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8 -1/2 7 -5/8" 29.7 L -80 Hydril 521 120 0 0 120 120 8 -1/2 7 26 L -80 BTC -Mod 5939 120 120 6059 5443 68 bbls; 172 sx (40% excess) 6 -1/8 3 -1/2 9.2 L -80 IBT -Mod 4152 5909 5302 10060 9437 140 bbls; 357 sx (35% excess) 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 11650 11650 3260 3260 3260 N/A Casing Length Size Cement Volume MD TVD Conductor /Structural 77.00 30" Driven 77 77 Surface 424.00 20" 540 sx Class G 424 424 Intermediate 2,512.00 13 -3/8" 2050 sx Class G 2512 2512 Production 8,667.00 9 -5/8" 815 sx Shoe / 300 sx DV collar 8,667.00 8667 Liner 1137 7" 335 sx Class G 9700 9700 Perforation Depth MD (ft): N/A Perforation Depth TVD (ft): N/A 20. Attachments: Filing Fee ❑ BOP Sketch El Drilling Program 0 Time v. Depth Plot El Shallow Hazard Analysis ❑ Property Plat El Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Printed Name Tim Brandenburg Title Drilling Manager Signature (_,-.% - Phone 263 -7657 Date 1/22/2009 — Commission Use Only Permit to Drill API WC'' Number: -'©/Q 50- ZS — G+- - SS " ' O/ Date: a • 4 • .0 requirements. If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Conditions of approval : Samples req'd: Yes No 2 Mud log req'd: Yes❑ No: 4C)(:)0 tSt .4- Ctz+ ca 5 00 `k, �imk -%o.o ,.I-1 measures: Yes No [' Directional svy req'd: Yes' [✓ No❑ `" \ 5 ls 1 `e, cry. S �o 1r v\ i 0 A-ACa -S,. S c\c■ C� Other: Z.-/ 0 r APPROVED BY THE COMMISSION D ATE: , COMMISSIONER / L Form 10 -401 Revised 12/2005 ! Submit D � •� Duplicate • Chevron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK AK 99519 -6247 Tel m a it 7657 E brandenburgt@chevron.com Email bandenburgt @chevron.com D January 22, 2009 E Commissioner I VE Alaska Oil & Gas Conservation Commission t s 2009 333 W. 7 Avenue Anchorage, Alaska 99501 Alaska Oil &Gas�,ns! comrrtissjp Re: Permit to Drill 10 -401 Anchorage Stump Lake Unit, SLU 41 -33RD Gas Development Well Dear Commissioner: Enclosed for your approval is a completed Permit to Drill (form 10 -401) for the Stump Lake Unit SLU 41 -33RD Gas Development Well. Work to abandon the original well, SLU 41 -33, was approved under sundry notice 308 -270. The scope of work covered under the sundry notice includes rig up of Nabors #129, pulling tubing, performing a scraper run, setting a bridge plug, and running the whipstock and mill assembly. It is our understanding that milling of the window cannot begin without approval of the Permit to Drill. We would like to request a variance from requirements of 20 AAC 25.035(e)(1)(C)(ii), requiring rams for each size of casing to be run in the well. During the casing of the 8 -1/2" intermediate hole section, we are planning to run a 4 preventer stackup. From top to bottom, we will run an annular preventer, variable rams 2 -7/8" x 5 ", blind rams, and 7" casing rams. The casing string run will be a tapered string of 7" 26# L -80 BTC -Mod by 7 -5/8" 29.7# L -80 Hydril 521. The 7 -5/8" Hydril will consist of 3 joints with a crossover to 7" BTC -Mod run at the top of the string. In the event of a well control incident, we are planning to pull out of hole and lay down the 7 -5/8 casing so that the BOPE can be closed in on the 7" casing. Nabors #129 has a triple derrick and should allow for pulling 2 full joints above the rotary table if needed, therefore only 1 joint would need to be layed down to get 7" casing across the BOPE cavities. Since the 7 -5/8" casing is the last 3 joints, any influx or stuck pipe issues are less likely to occur before making up the three 7 -5/8" joints. The 7 -5/8" Hydril is being run due to provide enough clearance for the 3 -1/2" long string and 1.660" heater string below the dual tubing hanger. We are committed to running a heater string on this well due to a history of hydrate and freezing problems at our Westside Cook Inlet fields and believe a heater string will be more reliable than a methanol or chemical injection mandrel with control line ran to surface. Tension rating for the 7 -5/8" is 683,000 lb and tensile rating for the 7" is 604,000 lb. Burst rating for the 7 -5/8" is 6,890 psi and for the 7" is 7,240 psi. Casing design ratings were run with the lower of each rating and are well above industry recommended safety factors. We would like to request a variance from requirements of 20 AAC 25.035(e)(1)(C)(i), requiring pipe rams for each size of tubing to be run in the well. During the drilling and casing of the 6 -1/8" production hole section, we are Union Oil Company of California / A Chevron Company http: / /www.chevron.com planning to run a 4 preventer stackup. From top to bottom, we will run an annular preventer, variable rams 2 -7/8" x 5 ", blind rams, and 4" pipe rams. The long string will be 3 -1/2" and the heater string will be 1.660 ". The heater string will be run after the 3 -1/2" long string is run. Prior to running tubing, the well will be completed with a 7" x 3 -1/2" liner and isolated from any openhole. The liner will not be perforated prior to this point and the annular preventer would be able to close in on the 1.660" if necessary. Therefore, running of the heater string separately w/o a 1.660" pipe ram should not present a risk to well control. We are targeting a spud date of February 12 Therefore, your earliest attention to this application will be greatly appreciated. If additional information is required, please contact either myself or Mr. Stan Porhola at 263 -7640. Sincerely, Timothy C. Brandenburg Drilling Manager TCB: stp Attachments: PTD Package Cc: Well File Engineer File — Stan Porhola Environmental — Megan Lewis Union Oil Company of California / A Chevron Company http: / /www.chevron.com Chevron 4101 Stump Lake Unit SLU 41 -33RD Gas Well Drilling Procedure Summary Permitted operations under Sundry Notice 308 -270 for SLU 41 -33 1. MIRU Nabors #129 drilling rig. 2. N/D F -block dual tree. 3. N/U BOPE equipment. Test BOPE to 250 psi /4000 psi. 4. Pull and L/D tubing and heater string. 5. P/U 4" drillpipe and casing scraper assembly. Displace diesel to mud. 6. RIH and scrape across planned window at +/- 2900' MD. POOH. 7. P/U and RIH w/ bridge plug on drillpipe or wireline. Set for base of whipstock at +/- 2950' MD. 8. Test casing and bridge plug to 2000 psi. POOH w/ setting tool. 9. Hang off BOPE and N/D DCB tubing head. 10. N/U 13 -5/8" x 11" casing spool for 7 -5/8" hanger. Test hanger to 5000 psi. 11. M/U BOPE equipmpent to new casing spool and test connection. 12. P/U whipstock and milling assembly. RIH and set whipstock anchor on bridge plug. Orient whipstock face w/ gyro. Proposed operations under Permit to Drill for SLU 41 -33RD 13. Mill window and drill 20' new formation. Pull back into the casing and conduct a Teak -off test or FIT test to 11.0 ppg EMW. 14. POOH and L/D mill assembly. 15. M/U 8 -1/2" directional BHA and RIH. Directionally drill 8 -1/2" hole to intermediate casing point at +/- 6,059' with 9.1 -10.0 ppg water - based mud. Utilize BHA w/ MWD, GR and Res/ Plan for 1 bit run. Perform wiper trips as necessary. 16. Condition hole and POOH. L/D bit and BHA. 17. Change out 4" pipe rams and install 7" casing rams. Test to 250/4000 psi. 18. R/U and run tapered 7 -5/8" x 7" casing. 19. M/U and test cement lines. Circulate and cement casing bringing cement to +/- 4000' MD. Bump top plug and test casing to 4000 psi. R/D cement equipment. 20. Hang off BOPE and N/U new Vetco tubing head. 21. M/U BOPE equipment to new tubing head. 3 Drilling Procedure Summary SLU 41 -33RD rev1- 0- 20090121.doc 1 Chevron • Stump Lake Unit SLU 41 -33RD Gas Well Drilling Procedure Summary 22. M/U 6 -1/8" directional BHA and RIH. Drill out float equipment, and 20' of new formation. Pull back into the casing and conduct a leak - off test or FIT test to 13.0 ppg EMW. 23. Directionally drill 6 -1/8" hole to TD at +/- 10,060' MD with 10.0 -11.6 ppg water -based mud. Utilize BHA w/ MWD, GR and Res Plan for 2 bit runs. Perform wiper trips as necessary. 24. Condition hole and POOH. L/D bit and BHA. 25. R/U and run open hole logging suite (Quad Combo: GR -Res, Den, '` Neu, Son) from TD to 6059' MD. POOH. L/D Quad Combo. 26. P/U and run FMI log (Formation Micro Imager) from 10,060' to 8300' MD and 7450' to 6059' MD. POOH. Rig down wireline. 27. R/U and run 3 -1/2" liner (IBT -Mod). Set liner top +/- 150' above 7" shoe. 28. M/U and test cement lines. Circulate and cement liner bringing cement above liner top. Drop wiper plug and displace w/ 6% KCI and bump top plug to 4000 psi. Check floats. 29. Liner hanger to be set before cement job or during displacement. 30. P/U and set liner top packer. Circ clean above liner top. Test liner /packer to 4000 psi. R/D cement equipment. 31. POOH and L/D liner running tool. 32. L/D drillpipe out of derrick. 33. R/U and run 3 -1/2" completion (TC -II tubing) w/ seal assembly and land in top of liner tie -back. 34. Set SAB -3 Permanent packer +/- 40' above liner top. 35. Space out and land tubing. Set tubing hanger and test packoff to 5000 psi. 36. Test tubing to 5000 psi. 37. RIH w/ 1.660" heater string and set in tubing hanger. 38. Test tubing x casing annulus to 1500 psi. 39. N/D BOPE. N/U and test dry tree to 5000 psi. 40. R/D and Release Rig. Proposed rigless completion to be submitted under a separate sundry notice for SLU 41 -33RD 1. Mobilize coil tubing and frac equipment. (Mobilization contingent upon barge availability across Cook Inlet). 2. Perforate w/ coil. Fracture stimulate down the tubing. 3 Drilling Procedure Summary SLU 41 -33RD rev1- 0- 20090121.doc 2 • • Chevron Well Name: SLU 41 -33RD Field: Stump Lake Unit Completion: Proposed v9.0 All depths corrected to new RKB New rig RKB = 5.73' + Old rg RKB New Surface Location: l J I Conductor: 30 ", to 83' Stump Lake Pad RKB 16.8' Above GL Surface Casing: GL 28.30' Above MSL 20 ", 94 ppf, H -40, BTC to 430' X: 375,758 Y: 2,655,295 Sec. 33, T14N, R8W, SM Old Surface Location: RKB 14.0' Above GL Intermediate Casing: GL 25.37' Above MSL , 13%", 72 ppf, N -80, BTC to 2518' X: 375,769 Y: 2,655,292 Intermediate Casing: (WINDOW) I 8 1/2" Hole I 9 % ", 43.5 ppf, P -110, BTC to 2900' Intermediate Casing Cement Intermediate Casing: 12.0 ppg Lead cmt from 4000' - 6059' 7 -5/8 ", 29.7 ppf, L -80, Hydril 521 from 0 to 120' 68 bbl (40% OH Excess) 7 ", 26 ppf, L -80, BTC -Mod from 120' to 6059' Fracture Gradients: 6 -1/8" Hole ] . Shoe @ 2900' MD (2900' TVD) = 11.0 ppg Shoe @ 6059' MD (5443' TVD) = 13.0 ppg Production Liner Casing Cement TD @ 10,060' MD (9437' TVD) = 14.4 ppg 12.0 ppg Lead cmt from 5809' - 10,060' 140 bbl (35% OH Excess + 100' top of liner) Production Tubing: 3'/2', 9.2 ppf, L -80, TC -II to 5,909' w/ 10' seal assembly stabbed into tieback Heater String Tubing: 1.660 ", 3.02 ppf, J -55, CS- Hydril to 3500' • Production Liner. Completion: 31/2', 9.2 ppf, L -80, IBT -Mod liner from 5909' - 10,060' - SAB -3 Perm Packer @ 5869' 7" x 5" Rotatable FlexLock liner hanger w/ ZXP Packer & Tieback sleeve at 5909' PBTD = 9,980' MD TD = 10,060' MD 4 WBD SLU 41 -33RD Proposed v9.0.xls Jan 19, 2009 Drawn by: STP Stump Lake ---- --%0' 1 C hevron SLU 41 -33RD AFE Time Depth vs. Time Actual Updated: Jan 19, 2009 NPT = 0 hrs (0% of Actual Time) 1000 Actual / AFE Days = 0/42 -- 0 days behind MIRU Nabors 129 Pull Tubing Mill Window Actual / AFE Cost = 0.000/9.745 -- 9.745 remain 2000 — • \ / 8 -1/2" AROP = 37.8'/hr (Planned) 3000 6 -1/8" Upper A(2OP = 17.6' /h (Planned) I I 4000 I I A 6 -1/8" Lower A�2OP = 14.2'/hr (Planned) 14 5000 J L 1 8 -1/2" HA 60 00 � - - � -' `- -` 7" Casing 7000 4 6-1/8" Hole III 8000 — t , r , 3 -112" 3 -1/2" DeMobe OH Logs Liner Tubing Nabors 129 9000 -' r r - 7 r Bit/BHA 7' I f Change 10000 T r 6 -1/8" Hole 11000 -' I 1 I I I r 0 5 10 15 20 25 30 35 40 45 50 Time (Days) Chevron %. $cblumberger 44- 1 RD (P8) Proposal %. SLU 3 ( ) p Report Date: January 19, 2009 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: Chevron Vertical Section Azimuth: 319.380° Field: Stump Lake Unit Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: Stump Lake Unit / 41 -33 _ S4H TVD Reference Datum: KB Well: SLU 41 -33 - ' Ii T R eference Elevation: 45.10 ft relative to MSL • Borehole: 41 -33RD ea S Sea Bed 1 Ground Level Elevation: 28.30 ft relative to MSL • UWIIAPI#: 502832005501 F Magnetic Declination: 19.053° Survey Name / Date: 41 -33RD (P8) / January 19, 2009 Total Field Strength: 55760.068 nT Tort 1 AHD/ DDI 1 ERD ratio: 95.701° / 1753.37 ft / 5.253 / 0.186 Magnetic Dip: 74.086° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: February 19, 2009 Location LatlLong: N 61.26582820, W 150.70584335 Magnetic Declination Model: BGGM 2008 • Location Grid WE YIX: N 2655295.200 ftUS, E 375758.030 ftUS North Reference: True North Grid Convergence Angle: - 0.61893279° Total Corr Mag North a True North: +19.053° Grid Scale Factor: 0.99991756 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub -Sea TVD TVD Vertical NS EW Mag 1 Gray DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty (ft ) (deq) (deq) (ft ) (ft ) (ft ) (ft ) (ft ) (deg) (deg /100ft ) Index (ftUS) (ftUS) Top Window 2900.00 0.00 319.33 2854.90 2900.00 0.00 0.00 0.00 - 0.00 0.00 2655295.20 375758.03 N 61.26582820 W 150.70584335 KOP Bld 4/100 3000.00 0.00 319.33 2954.90 3000.00 0.00 0.00 0.00 319.33M 0.00 0.00 2655295.20 375758.03 N 61.26582820 W 150.70584335 3100.00 4.00 319.33 3054.82 3099.92 3.49 2.65 -2.27 319.33M 4.00 1.14 2655297.87 375755.78 N 61.26583544 W 150.70585627 3200.00 8.00 319.33 3154.25 3199.35 13.94 10.57 -9.08 HS 4.00 2.05 2655305.87 375749.06 N 61.26585712 W 150.70589496 3300.00 12.00 319.33 3252.71 3297.81 31.30 23.74 -20.40 HS 4.00 2.58 2655319.16 375737.89 N 61.26589314 W 150.70595923 3400.00 16.00 319.33 3349.72 3394.82 55.49 42.09 -36.16 HS 4.00 2.95 2655337.67 375722.33 N 61.26594331 W 150.70604877 3500.00 20.00 319.33 3444.81 3489.91 86.38 65.52 -56.30 HS 4.00 3.24 2655361.32 375702.45 N 61.26600741 W 150.70616315 3600.00 24.00 319.33 3537.51 3582.61 123.84 93.93 -80.70 HS 4.00 3.48 2655389.99 375678.35 N 61.26608511 W 150.70630180 3700.00 28.00 319.33 3627.37 3672.47 167.67 127.17 - 109.27 HS 4.00 3.67 2655423.53 375650.15 N 61.26617603 W 150.70646406 3800.00 32.00 319.33 3713.95 3759.05 217.65 165.09 - 141.85 HS 4.00 3.85 2655461.79 375617.99 N 61.26627974 W 150.70664913 3900.00 36.00 319.33 3796.84 3841.94 273.56 207.49 - 178.28 HS 4.00 4.00 2655504.59 375582.02 N 61.26639572 W 150.701 4000.00 40.00 319.33 3875.63 3920.73 335.12 254.18 - 218.40 HS 4.00 4.14 2655551.70 375542.41 N 61.26652342 W 150.70708399 4100.00 44.00 319.33 3949.92 3995.02 402.02 304.92 - 261.99 HS 4.00 4.26 2655602.91 375499.37 N 61.26666221 W 150.70733166 End Bld 4196.14 47.85 319.33 4016.79 4061.89 471.07 357.30 - 307.00 -- 4.00 4.37 2655655.76 375454.94 N 61.26680547 W 150.70758732 Drp 4/100 5269.02 47.85 319.33 4736.83 4781.93 1266.44 960.56 - 825.34 LS 0.00 4.82 2656264.54 374943.18 N 61.26845545 W 150.71053212 5300.00 46.61 319.34 4757.87 4802.97 1289.18 977.81 - 840.16 LS 4.00 4.84 2656281.95 374928.55 N 61.26850263 W 150.71061632 5400.00 42.61 319.35 4829.05 4874.15 1359.39 1031.08 - 885.90 LS 4.00 4.90 2656335.70 374883.39 N 61.26864830 W 150.71087620 5500.00 38.61 319.38 4904.95 4950.05 1424.46 1080.46 - 928.28 LS 4.00 4.96 2656385.53 374841.55 N 61.26878336 W 150.71111698 5600.00 34.61 319.40 4985.21 5030.31 1484.08 1125.72 - 967.09 LS 4.00 5.00 2656431.20 374803.24 N 61.26890715 W 150.71133747 5700.00 30.61 319.43 5069.44 5114.54 1537.96 1166.63 - 1002.14 LS 4.00 5.05 2656472.49 374768.64 N 61.26901905 W 150.71153661 5800.00 26.61 319.47 5157.21 5202.31 1585.82 1203.01 - 1033.26 LS 4.00 5.09 2656509.19 374737.92 N 61.26911853 W 150.71171342 5900.00 22.61 319.53 5248.11 5293.21 1627.45 1234.66 - 1060.29 179.66R 4.00 5.12 2656541.14 374711.22 N 61.26920511 W 150.71186705 WellDesign Ver SP 2.1 Bld( doc40x_100) 41 -33 \SLU 41- 33441- 33RD \41 -33RD (P8) Generated 1/19/2009 11:34 AM Page 1 of 2 Measured Vertical Mag 1 Grav Directional Comments Depth Inclination Azimuth Sub -Sea TVD TVD Section NS EW Tool Face DLS Difficulty Northing Easting Latitude Longitude (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg) (degl100ft ) Index (ftUS) (ftUS) 6000.00 18.61 319.60 5341.69 5386.79 1662.64 1261.44 - 1083.12 179.59R 4.00 5.15 2656568.16 374688.69 N 61.26927835 W 150.71199673 7" Csg 6059.02 16.25 319.66 5398.00 5443.10 1680.32 1274.91 - 1094.57 179.53R 4.00 5.17 2656581.75 374677.39 N 61.26931518 W 150.71206178 Sterling 56 -2 6090.17 15.00 319.70 5428.00 5473.10 1688.71 1281.30 - 1100.00 167.84R 4.00 5.18 2656588.20 374672.03 N 61.26933267 W 150.71209262 6100.00 14.62 320.03 5437.50 5482.60 1691.22 1283.22 - 1101.61 167.52R 4.00 5.18 2656590.14 374670.43 N 61.26933793 W 150.71210182 6100.23 14.61 320.04 5437.73 5482.83 1691.28 1283.27 - 1101.65 -- 4.00 5.18 2656590.18 374670.40 N 61.26933805 W 150.71210204 6162.88 14.61 320.04 5498.35 5543.45 1707.07 1295.38 - 1111.80 LS 0.00 5.19 2656602.40 374660.38 N 61.26937117 W 150.71215970 6200.00 13.12 320.04 5534.39 5579.49 1715.97 1302.19 - 1117.51 LS 4.00 5.20 2656609.28 374654.74 N 61.26938981 W 150.71219216 6300.00 9.12 320.04 5632.49 5677.59 1735.25 1316.98 - 1129.90 LS 4.00 5.22 2656624.19 374642.52 N 61.26943024 W 150.71226254 6400.00 5.12 320.04 5731.70 5776.80 1747.65 1326.48 - 1137.86 LS 4.00 5.24 2656633.78 374634.66 N 61.26945622 W 150.71230778 6500.00 1.12 320.04 5831.53 5876.63 1753.09 1330.65 - 1141.36 0.00M 4.00 5.26 2656637.99 374631.21 N 61.26946764 W 150.71232765 End Drp 6528.05 0.00 0.00 5859.58 5904.68 1753.37 1330.86 - 1141.54 -- 4.00 5.27 2656638.20 374631.03 N 61.26946822 W 150.715 Beluga 6822.47 0.00 0.00 6154.00 6199.10 1753.37 1330.86 - 1141.54 - 0.00 5.27 2656638.20 374631.03 N 61.26946822 W 150.71 65 10059.97 0.00 0.00 9391.50 9436.60 1753.37 1330.86 - 1141.54 - 0.00 5.25 2656638.20 374631.03 N 61.26946822 W 150.71232865 TD / 3 -1/2" Lnr 10060.47 • 0.00 0.00 9392.00 9437.10, 1753.37 1330.86 - 1141.54 -- 0.00 5.25 2656638.20 374631.03 N 61.26946822 W 150.71232865 Survey Error Model: SLB ISCWSA version 24 * ** 3-D 95.00% Confidence 2.7955 sigma Surveying Proq: MD From (ft). MD To (ft l EOU Freq Survey Tool Type Borehole -> Survey 0.00 16.80 Act -Stns SLB_BLIND -Depth Only 41 -33 -> 41 -33 16.80 300.00 Act -Stns SLB_BLIND 41 -33 -> 41 -33 300.00 2900.00 1/100.00 SLB_BLIND 41 -33 -> 41 -33 2900.00 6059.02 1/100.00 SLB_MWD - STD^ ^1 41 -33RD -> 41 -33RD (P8) 6059.02 10060.47 1/100.00 SLB_MWD - STD^ ^2 41 -33RD -> 41 -33RD (P8) Legal Description: Northing (Y) fftUS1 Easting (X) fftUS1 Surface : 4508 FSL 505 FEL S33 T14N R8W SM • 2655295.20 375758.03 Sterling 56 -2 : 509 FSL 1603 FEL S28 T14N R8W SM 2656588.20 374672.03 Beluga : 559 FSL 1645 FEL S28 T14N R8W SM 2656638.20 374631.03 BHL : 559 FSL 1645 FEL S28 T14N R8W SM . 2656638.20 374631.03 • WellDesign Ver SP 2.1 Bld( doc40x_100) 41- 33 \SLU 41-33\41-33RD \41-33RD (P8) Generated 1/19/2009 11:34 AM Page 2 of 2 Chevron 1%. • VVELL SLU 41 -33RD (P8) I FIELD Stump Lake Unit I STRUCTURE Stump Lake Unit Magnetic Parameters Surface Location NAD27 Alaska State Planes, 2ona 04, US Feel I iscellaneou Model: BOOM 2008 Dip: 74086' Date: February 19, 2939 Lat N611556.982 Northing: 265529520 SUS Grid Com: '061893279' S 41 s -33 TVO Ref: KB (45105 above MSL) Map Dec: +19053' FS: 55760.1 nT Lon: W150 12 21.036 Eastng: 37575803 SUS Sale Fad: 09999175632 Plan: 41-33RD (P8) Sew Date: January 19, 2009 -3000 -1500 0 1500 3000 4500 0 r • KBE s• 0 20" 1500 1500 733/8" 3000 Ka TPR B Vd^m 3000 0 E • Bid 4500 • • 4500 Drp 41100 7" Cag O O Sterling 56 -2 B) U 41 -33RD Tgt 1 c_ End Drp 6000 6000 a) Beluga U 41 -33RD Tgt 2 U 7500 7500 -L 9-5l8" 9000 9000 TO l 3 -112" Lnr 3RD (P8) 10500 10500 TD 1 -33 12000 - 12000 • -3000 -1500 0 1500 3000 4500 Vertical Section (ft) Azim = 319.38 °, Scale = 1(in):1500(ft) Origin = 0 NI-S, 0 E / -V Chevron i Schlumberger WELL FIELD STRUCTURE SLU 41 -33RD (P8) I Stump Lake Unit I Stump Lake Unit Me90050 Panmears I Surtaca Location NAD22 Alaska State Planes, Zone 04, US Feet I Miawllanaous Model'. BGGM 2008 Dip: 74.086' Date: February 19,2009 Let N61 15 56 982 Northing: 2655295 20 Grd Cony: -0.81893279• Slot: 41 -33 TVD Ref KB (45.10 R above MSL) Ma90ec: +19053' FS: 55760.1 nT Lon: W150 42 21 036 Eastrrg 37575803 BUS Sc a Fad: 09999175632 Plan: 41 33RD (P8) Spry Date : January 19, 2009 -1200 -1000 -800 -600 -400 -200 0 TD 13 -112•' Lir 41 -33RD (P8) 4 Beluga 1400 ® S - r " 41 -33RD T�12 , s•••• 1400 Sterling 56 -2 ' • End Drp ,4 SLU 41 -33RD Tg11 7 4. 1200 - 1200 1000 Dry 4/100 1000 A A A z 800 0 4••° 800 II 0) V 600 600 N V V V 400 400 End Bid 200 •••• o o•••• 200 41 -33 0 ...4 0 KOP Bid 4/100 r Top Window KBE •• 13318" -1200 -1000 -800 -600 -400 -200 0 :« W Scale = 1(in):200(ft) E »> t$ Chevron Maximum Anticipated Surface Pressure Calculation Stump Lake Unit SLU 41 -33RD Cook Inlet, Alaska Assumptions: 1. Based on offset drilling & well test data, the normal pore pressure gradient is predicted to be a 0.440 psi /ft gradient from surface to planned total depth at 9,437' TVD BRT. Some zones at Stump Lake are geo- pressured (as high as ' 0.55 psi /ft) and sub - normally pressured (as low as 0.26 psi /ft). These pressures are noted on the geo -tops attachment. 2. The M.A.S.P. during drilling operations will be govemed by the 7" shoe frac gradient, and is calculated based on a full column of gas between the 7" shoe and the surface. The shoe f or SLU 41 -33RD at 5,443' TVD will be between the shoe depths of offset wells on the Ivan River and Stump Lake pad, ranging from 2943' to 8677' TVD. Leak -off or formation integrity tests ranged from 14.7 ppg to 20.2 ppg (0.764 psi /ft and 1.050 psi /ft). This offset LOT /FIT data from Ivan River and Stump Lake is useful for relatively accurate kick tolerance & MASP calculations. 3. The M.A.S.P. Maximum Bottom Hole Pressure is estimated from SIBHP minus the gas hydrostatic pressure between the SL 81 -6 sand & the surface. This sand has a higher pore pressure than at TD (0.55 vs. 0.44 psi /ft). ' M.A.S.P. Maximum Bottom Hole Pressure: Max. pore pressure at SL 81 -6: = 8,171 ft. x 0.550 psi /ft = 4494 psi r M.A.S.P. (tbg leak at surface) = 4494 psi - (0.1 psi /ft * 8,168 ft) = = 3677 psi M.A.S.P. While Drilling 6 -1/8" hole at 9,437' TVD: Max. Est. Frac pressure at 7" shoe = 5443 ft. x 0.676 psi /ft = 3679 psi M.A.S.P. during drilling = 3679 psi - (0.1 psi /ft x 5443 ft.) _ = 3135 psi M.A.S.P. While Drilling 8 -1/2" hole at 5,443' TVD: Max. Est. Frac pressure at 9 -5/8" window = 2900 ft. x 0.572 psi /ft = 1659 psi M.A.S.P. during drilling = 1659 psi - (0.1 psi /ft x 2900 ft.) = = 1369 psi Calculation & Casing Design Factors to. Chevron Stump Lake Unit SLU 41 -33RD Cook Inlet, Alaska WELL: SLU 41 -33RD FIELD: Stump Lake Unit DATE: 19 -Jan -09 DESIGN 8Y: Stan Porhola Sect. 1 Window MUD WT. 9.1 PPG MASP= 1,369 psi` Sect. 2 8 1/2" hole MUD WT. 9.1 -10.0 PPG MASP= 3,135 psi' Sect. 3 6 1/8" hole MUD WT. 10.0 -11.6 PPG MASP= 3,677 psi" Maximum Bottom Hole Pressure TENSION MINIMUM COLLAPSE COLLAPSE WEIGHT TOP OF STRENGTH PRESS @ RESIST. MINIMUM DESCRIPTION W/O BF SECTION TENSION WORST CASE BOTTOM w/o TENSION WORST CASE MASP YIELD WORST CASE flik SECTION CASING BOTTOM TOP LENGTH WT. GRADE THREAD LBS LEIS 1000 LBS SF TENSION PSI" PSI SF COLL. 12111 PSI"' $F BURST 1 9-5/8" 2,900 0 2900 43.5 N -80 BTC 126,150 126,150 1005 7.97 1,276 3,810 2.99 1,369 5,930 4.33 TVD 2,900 0 2 7" 6,059 0 6059 26 L-80 BTC -Mod 157,534 157,534 604 3.83 2,395 5,410 2.26 3,677 6,890 1.87 TVD 5,443 0 3 3-1/2" 10,060 0 10060 9.2 L -80 IBT -Mod 92,552 92,552 159 1.72 5,190 10,530 2.03 3,677 7,240 1.97 TVD 9,437 0 • See attached sheet for calculation of MASP "• Collapse pressure is calculated; Normal Pressure Fluid Gradient for external stress (0.440 psi/ft for 7" casing and 0.550 psi/ft for 3-1/2" liner) and the casing evacuated for the intemal stress (0 psi/ft) • "' Minimum Yield Calculated using the lower of 7 -5/8" 29.7# L -80; 7" 26# L -80; (6890 psi for 7 -5/8 ", 7240 psi for 7" L -80) CASING DETAILS (Tapered 7-6/8" x 7" Casing String) Size Weight Grade Conn Burst Collapse Tension 7 -5/8" 29.7 L-80 Hydril 521 6890 4790 683,000 (INCLUDED IN STRING TO PROVIDE ADEQUATE CASING ID TO ALLOW LONG STRING x HEATER STRING CLEARANCE BELOW WELLHEAD) 7" 26.0 L-80 BTC -Mod 7240 5410 604,000 Chevron Stump Lake Unit %NO SLU 41 -33RD Gas Well Cement Program 7" Casing (8 -1/2" Hole to 6,059' MD): Cement volume based on annular volume plus 40% open hole excess and shoe joint(s). The job will consist of a lead only and cement will be brought to 4,000' MD. The estimated total volume is as follows: Lead: 2059' X 0.1268 cuft/ft (8-1/2" x 7 ") X 1.4 = 366 cuft = 164 sxs (2.24 yield) 80' shoe joint X 0.2148cuft/ft = 17 cuft = 8 sxs (2.24 yield) TOTAL: 366 + 17 = 383 cuft or 172 sxs 3 -1/2" Liner (6 -1/8" Hole to 10,060' MD): Cement volume based on annular volume plus 35% open hole excess, 100' volume pumped above the liner top. The job will consist of a lead only and cement will be brought to 5,809' MD (100' above Liner Top). Any excess cement above the liner top will be circulated out after setting the liner hanger. The estimated total volume is as follows: Lead: 4,001' X 0.1378 cuft/ft (6 -1/8" x 3 -1/2 ") X 1.35 = 744 cuft = 333 sxs (2.24 yield) Lead: 250' X 0.1480 cuft/ft (6.276" x 3 -1/2 ") X 1.35 = 50 cuft = 22 sxs (2.24 yield) 90' shoe joint X 0.0488 cuft/ft = 5 cuft = 2 sxs (2.24 yield) TOTAL: 744 + 50 + 5 = 799 cuft or 357 sxs 9 Cement Program 41- 33RD.doc 1 1/19/2009 Chevron • • IWO Stump Lake Unit °WI SLU 41 -33RD Gas Well Cement Program Cement Type and Design: Intermediate Casing, 7 ", Lead Cement Type: Class G Density: 12.0 ppg Cement: 172 sx Yield: 2.24 ft /sx Mix Water: 9.71 gal /sx Slurry Volume: 68 bbl Additives: BA -90 15.000% BWOC Silica Static Free 0.500% BWOC Anti - Static FL -63 1.200% BWOC Fluid Loss Additive CD -32 1.000% BWOC Dispersant FP -6L 1ga1/100 sx Anti -Foam Sodium Metasilicate 0.300% BWOC Accelerator LW -7 -6 10.000% BWOC Light- weight additive Production Liner, 3 -1/2 ", Lead Cement Type: Class G Density: 12.0 ppg Cement: 357 sx Yield: 2.24 ft /sx Mix Water: 9.70 gal /sx Slurry Volume: 140 bbl Additives: BA -90 15.000% BWOC Silica Static Free 0.050% BWOC Anti - Static FL -63 1.200% BWOC Fluid Loss Additive CD -32 1.000% BWOC Dispersant FP -6L 1 gal /100 sx Anti -Foam Sodium Metasilicate 0.300% BWOC Accelerator LW -7 -6 10.000% BWOC Light- weight additive R -3 0.350% BWOC Retarder 9 Cement Program 41- 33RD.doc 2 1/19/2009 Chevron %101 Stump Lake Unit SLU 41 -33RD Gas Well Mud Program Intermediate Hole Recommendations Mud Type: 6% KCI, EZ Mud (Water- based) Properties: Depth Del_mM Viscosity Plastic Viscosity Yield Point API FL �H 2900 -6059' 9.1 —10.0 40 -50 8 -25 20 -28 <5 8.5 -9.5 System Formulation: 6% KCI, Clayseal Product Concentration Water 0.905 bbl KCI 19.8 ppb (30K chlorides) KOH 0.2 ppb (9 pH) Barazan D 1.25 ppb (as required 35 YP) PAC L 1 ppb Dextrid 1 ppb Clayseal 0.6 gal (0.2 initially) X -Cide 207 0.015 ppb (1 can per 400 bbl) Baracor 700 1 ppb Barascav D 0.5 ppb (maintain per dilution rate) Baroid As required* Production Hole Recommendations Mud Type: 6% KCI, EZ Mud (Water- based) Properties: Depth Density Viscositv Plastic Viscosity Yield Point API FL 6059 -8500' 10.0 -11.1 40 -50 6 -15 18 -25 _ <5 8.5 -9.5 • 8500 —TD 11.1 -11.6 40 -50 6 -15 18 -25 <5 8.5 -9.5 System Formulation: 6% KCI, Clayseal Product Concentration Water 0.905 bbl KCI 19.8 ppb (30K chlorides) KOH 0.2 ppb (9 pH) Barazan D 1.25 ppb (as required 35 YP) PAC L 1 ppb Dextrid 1 ppb Clayseal 0.6 gal (0.2 initially) X -Cide 207 0.015 ppb (1 can per 400 bbl) Baracor 700 1 ppb Barascav D 0.5 ppb (maintain per dilution rate) Baroid As required* *There will be an adequate stock of Barite on location to increase mud weight by 1.5 ppg for entire mud system Monitoring Equipment to be used on the circulating system: • Flow Show — Gauge for returns • Pit Volume Totalizer System • Mud /Gas Detection System for Methane and H • 10 Mud Program 41- 33RD.doc 1 1/19/2009 Chevron Stump Lake Unit ° 00 1 SLU 41 -33RD Gas Well Drilling Waste Plan Drilling Waste Plan The drilling operations will utilize water -base mud for all drilling. Approved Class II wastes such as cuttings, liquids and used mud will be hauled by Super Sucker or Vacuum Truck from the Stump Lake 41 -33RD well location to the Grind & Inject unit set up on the Ivan River pad. The Grind & Inject unit will utilize IRU 13 -31 (PTD No. 192 -088) or IRU 14 -31 (PTD No.175 -008), both currently active Class II Disposal wells. In the case that G &I is not operable and cuttings volumes exceed the current storage capacity, cuttings will be stored in cuttings totes and stored in a temporary waste storage area pending re- established injection operations. Used fluids waiting for G &I will be stored in upright tanks on location. Considering the small hole diameter of the Stump Lake sidetrack, current storage capacity should be more than adequate for both cuttings and fluids. 11 Drilling Waste Plan.doc 1 1/19/2009 Chevron • k101 Stump Lake Unit SLU 41 -33RD Gas Well Log /Core /Test Programs LOGGING Intermediate Hole, 8 -1/2" 2,900' - 6,059' MD: BHA: Mud Motor (6 -3/4 ") MWD: Directional LWD: Gamma Ray, Resistivity Open Hole: None Cased Hole: None Production Hole, 6 -3/4" 6,059' - 10,060' MD: BHA: Mud Motor (4 -3/4 ") MWD: Directional LWD: Gamma Ray, Resistivity Open Hole: Gamma Ray, Resistivity, Density, Neutron, Sonic Open Hole: FMI (6059' — 7450'; 8300' — 10,060') Cased Hole: None CORING None Planned COMPLETION /TESTING Following rig demobilization, coil tubing and frac equipment will be mobilized to complete the well. The completion timing will depend on the availability of barging across Cook Inlet to move the coil tubing and frac equipment. Once mobilized, the well will be cleaned out and fracture stimulated in several intervals in the Tyonek. Production of the well will be from the well tree thru buried flowline from the well location to the Stump Lake production facilities. All fluid volumes will be metered. 12 Log- Core -Test Programs 41- 33RD.doc 1 1/19/2009 . 0 to. Ch evron ESTIMATED GEOLOGIC TOPS AND CORRELATIONS SLU 41 -33RD Elevation, GL 28.3 RKB above GL 16.8 Zone / Pore Depths ( +/- 50') Marker Lithology Fluid Target* Press (ppg) MD TVD TVDSS Beluga Coal Coal Gas/Water N/A 8.5 5951 5341 -5296 Sterling Lower Sand Gas/Water Secondary 8.5 6030 5415 -5370 SL 56 -2 Sand Gas/Water Secondary 8.5 6090 5473 -5428 Beluga Sand Gas/Water Secondary 8.5 6313 5691 -5646 Beluga Conglom Sand /Cong Gas/Water Secondary 8.5 6676 6053 -6008 SL 66 -3 Sand Gas/Water Secondary 5.0 - 6.5 7162 6539 -6494 SL 66 -8 Sand Gas/Water Secondary 5.0 - 6.5 7223 6600 -6555 SL 67-4 Sand Gas/Water Secondary 5.0 - 6.5 7286 6663 -6618 SL 67 -6 Sand Gas/Water Secondary 5.0 - 6.5 7311 6688 -6643 SL 68 -6 Sand Gas/Water Secondary 5.0 - 6.5 7408 6785 -6740 Tyonek Coal Gas/Water N/A 8.5 8344 7721 -7676 SL 77 -9 Sand Gas/Water Primary 8.5 8430 7807 -7762 SL 81 -6 Sand Gas/Water Primary 10.6 8794 8171 -8126 SL 92 -4 Sand Gas/Water Primary 9.6 9871 9248 -9203 TD Siltstone Water Well TD 8.5 10060 9437 -9392 *Current Cement Design will isolate all fresh water and hydrocarbon zones. 7" Casing Cement coverage up the 9 -5/8" to planned top of 4000' MD / 3921' TVD 3 -1/2" Liner Cement to liner top @ 5909' MD / 5302' TVD • • UNOCAL s:5 GENERAL INPUT DATA Field Stump Lake Well Name 41 -33RD RT -MSL 16.8 ft Water Depth 0 ft Sea Water Gradient 0.447 psi /ft Casing Size to be Designed 7 inch Hole Size Drilled for This Casing _ 8 -1/2 inch DESIGN METHOD 1: From TD up to find the shallowest allowable shoe depth Hole Size Below the Shoe 6 -1/8 inch Next Section Total Vertical Depth 9,434 ft TVD RKB Next Section Total Vertical Depth _ 9,417 ft TVD BML Next Section Gas Gradient (first approximation: 0.089) 0.100 psi /ft Kick Intensity (Swab kick = 0.0 ppg intensity) 0.0 PPG Mud Weight _ 11.6 PPG Estimated Formation Pressure at Next Section TD 11.6 PPG EMW Fracture Gradient 0.68 psi /ft Kick Tolerance 10.0 bbl Drill Pipe Outside Diameter _ 4 inch (Calculation results acceptable. Minimum shoe depth = 5,362 ft TVD RKB 1 DESIGN METHOD 2: From upper casing shoe down to find the deepest hole which can be drilled without fracturing the upper casing shoe Upper Casing Size 9 -5/8 inch Upper Casing Shoe Depth _ 2,900 ft TVD RKB Upper Casing Shoe Depth 2,883 ft TVD BML Upper Gas Gradient (first approximation: 0.023) _ 0.100 psi /ft Hole Size below the Upper Casing Shoe _ 8 -1/2 inch Kick Intensity (Swab kick = 0.0 ppg intensity) 0.0 PPG Mud Weight _ 10.0 PPG Estimated Formation Pressure _ 10.0 PPG EMW Fracture Gradient 0.57 psi /ft Kick Tolerance 10.0 bbl Drill Pipe Outside Diameter 4 inch Calculation results acceptable. Maximum shoe depth = 5,844 ft TVD RKB 1 mdb /03jan01 Chevron 11 40 LEAK OFF TEST PROCEDURE 1. Clean out the rathole below the shoe, and drill 20' of new hole. Circulate and condition mud. 2. Pull the drill string into the shoe. Rig up to observe annulus pressures. 3. Close the pipe rams and pump down the drillpipe at a slow rate (1/4 - 1/3 BPM) if exposed formation is permeable. A non - permeable formation should be step tested to a predetermined pressure. 4. Measure the volume pumped and plot annulus pressure -vs- cumulative volume pumped. Compare annulus pressure to drill pipe pressure and confirm both are the same. Record and plot pressure versus volume pumped. The pumps should be shut down immediately upon indication of leak -off. Record the inital, shut down pressure and the pressure after 1, 2, and 3 minutes. 5. Release pressure and record the volume of fluid recovered in the trip tank. The point "B" shown in the attached graph at which the plot of drillpipe pressure stops increasing equally as the volume is pumped is called the P.I.T. limit, Leak Off, or pressure integrity test limit. The leak -off pressure is calculated as follows: Leak -off (EMW) = Mud weight in hole + P.I.T. (PSI) (0.052) X (shoe depth in TVD ft.) This equivalent mud weight should be made known to all drilling personnel to ensure it is not exceeded. See the drilling procedure for guidelines on expected LOT's or pressure integrity test limits for each casing shoe. B D SURFACE PRESS. TYPICAL PIT PLOT (psi) A VOLUME PUMPED SHUT -IN -TIME MB) (MIN) NOTES: Point "A" will have some variance until the system begins to pressure up. Point "B" is the leak off and is abbreviated LOT. Point "C" is known as the injection pressure and is usually dependent on rate. Point "D" is known as the fracture closure pressure and may not stabilize if permeable formations are exposed. • 0 28 27 SEC. LINE NOT TO SCALE NE COR S33 33 34 N: 2656061.225 E: 376270.091 • LATITUDE: 6116'04.579"N LONGITUDE: 150'42'10.733"W 4., R SECTION 33 �� 1 T14N, R8W �� Q �..QFA�g s ll l � A „� SM .., AK w ` -J —� :. ,, , . . -v /0 a R� , :. M. SCOTT M cLANE ; ' _ i 4928 —S 0 �Q F- �`- � � 0 a? � ��t,- 13 e _ l tss, t M- w z W�.� . ' 411 01010. i MOWING 2 4' W 44 11.. 4... e ff; . 0 ...., Cn Rhp 28' 6 STUMP LAKE PAD 4 .______1 505' FEL N j SLU 41 -33 RD � � WELL ` AS -BUILT f fl : 29 NORTH _,_ 27' 28' E pAD 0 SCALE 100 200 2 ,\ \ I _ '' •` SLU 41 -3 RD SURVEY NOTES WELL AS -BUILT N:2655295.204 1. HORIZONTAL DATUM IS NAD27 DERIVED FROM AN E:375758.026 NADCON CONVERSION OF NAD83 (CORS96) (EPOCH 2003.00) COORDINATES. LATITUDE:61 °15'58.982 "N 2. CORS STATIONS "KEN1 ", "TSEA ", AND "ZAN1' WERE USED LONGITUDE:150 °42'21.036"W FOR AN OPUS SOLUTION AT CP-1 (083070). NAD27 ASP ZONE 4 3. VERTICAL DATUM IS REFERENCED TO THE NAVD88, AND ELEV. 28.3' IS BASED ON THE GPS DERIVED OPUS SOLUTION (GEOD06 NAVD88 APPROX. MSL HEIGHTS). 505' FEL , 772' FNL SLU 41 -33 RD Ch"ivron AS -BUILT SURFACE LOCATION STUMP LAKE UNIT, BELUGA AK LOCATION: SECTION 33, TOWNSHIP 14 /11 ENGINEERING - TESTING NORTH, RANGE 8 WEST, SEWARD MERIDIAN SURVEYING - MAPPING P.O. BOX 468 ALASKA t n SOLDOTNA, AK. 99669 JOB NO. 0 1 VOICE: (907) 283 -4218 FAX: (907) 283 -3265 DWG. Callultin. Inc WWW.MCLANECG.COM 093001SLU41- 33RD_NAD27 Date: 1/13109 FIGURE: 1 • ADL326059 ADL326060 TD Location X: 374631 Y: 2656638 Target Location X: 374672 Y: 2656588 ‘DL058791 8790 89 Surface Location X: 375758 Y: 2655295 Legend • SLU 41 33RD Roads Wel Tracks 1500 ft., Target 1500 ft., TD 3000 ft., Target 3000 ft., TD N Leases mil" Unit Boundary 4 t. : 61 ' hevro ►; Wellpath SLU 41 -33RD 0 500 1 ,► Top Target & TD Radius Alaska State Plane Zone 4, NAD2 January 20, 200' • • SLU 41 -33RD BOP Stack Diagram - w/ Nabors 129 Underside of Rotary Table Drip Pan Planned Test Pressure Initial BOPE N/U 250/3500 psi See procedure step 3 11" Shaffer Annular 5M J C ' I I I 11" Shaffer 5M Dbl Gate 2 -7/8" x 5" VBR Pipe Rams —I I - I 11" Shaffer 5M Blind Rams I I L J To choke manifold ^ — ^ From kill line 3 5m 3' 1/8" ` 11° 5M 31/8" 31/8" a �� +" HCR 5m 7 Mud Cross 5m 5m _ I —' C 11" Shaffer 5M Single BOP I Ground Level 4" pipe rams Rig Mats '.i.. ` 1 ' , _ L. I ii" 5MCIW _ — Tubing Head -----------* 9 5/8" outlet I Double Studded Packoff - - -°' 16 -3/4" 3M CIW —�* Casing Head 13 -3/8" Surface 13 3/8" outlet 20" Conductor 30" Structural (driven) F Thl A > Well Cellar • • SLU 41 -33RD BOP Stack Diagram -w/ Nabors 129 Underside of Rota Table Drip Pan Planned Test Pressure 2nd BOPS N/U 250/3500 psi See procedure step 11 11" Shaffer Annular 5M C . / 1 I 11" Shaffer 5M Dbl Gate I 2 -7/8" x 5" VBR Pipe Rams J \ L I I 11" Shaffer 5M I Blind Rams \ i I To choke manifold �� – '^ From kill line 3� 5m g/ 1 /g 11" 5M '3/8" `TT 31/8" I o- HCR 5m - Mud Cross - 5m Sm a _ v / 1 Ground Level I 11" Shaffer 5M Single BOP I 4" pipe rams Rig Mats L_,� I 1 11 " 5M CIW J Casing Spool ---------- —0 �f 9 5 /8" outlet r 7 Double Studded Packoff 16 -3/4" 3M CIW Casing Head 13 -3/8" Surface 13 3/8" outlet 20" Conductor 30" Structural (driven) FT Well Cellar • I SLU 41 -33RD BOP Stack Diagram -w/ Nabors 129 Underside of Rotary Table Drio Pan 7 I Planned Test Pressure r 1 3rd BOPE N/U 250/3500 psi 11" Shaffer Annular See procedure step 21 5M �� l imr=m i 11" Shaffer 5M Dbl Gate 2 -7/8" x 5" VBR Pipe Rams LA I I / 1 11" Shaffer 5M Blind Rams ♦ 1 1 To choke manifold _ L J From kill line � �� 11" 5M A- HCR 5m 5m 5m 5m C7 Mud Cross t-- 5I .L Sm I a _ _ _ / \ C 11" Shaffer 5M Single BOP I I 4" pipe rams N. i Ground Level 11" 5M Vetco I / Tubing Head - - - -1 7 5/8" x 7" outlet Rig Mats " Casing 115M Spo ol -------------► 9 5 /8" outlet I Double Studded Packoff --11° 16 -3/4" 3M CIW Casing Head 13 -3/8" Surface —/� 13 3/8" outlet 20" Conductor 30" Structural (driven) ► FT A Well Cellar i i f 1 Nabors Alaska Driltin s. RIG 129E Material List • Item Descri. on 10-11 4-1/16" 10M Gate Valve 3, 4, 7, 8, 9 3-1/8" 5M Gate Valve 1, 2, 5, 6, 12 3-1/16" 10M Manual Choke Valves A 2- 9/16" 10M SWACO Suer Choke B 3- 1/16" 10M Manual Choke 4s= 0 0 0 I" - p A i . (11 fir (!S 4D : .,,, ... ..„ qa .. ...,„ Legend 111 — Whiles Handle Valves Normally Open _ .< . ....... A ► Red Handle Valves 7 Normally Closed Inlet Date 12 -23 -05 Rev. 3 ss -r 5r-O • • i -- II II Ill 111111_I —� - -- V,_ +,� -I -- II rr a u II 1 o i i 11 X ANA1;■ It ! 111111111 r! II __ _ z- it NANY orgiVokird-IIIIIIIIIIII — _ , �� [] l - 1 !IIIIIIIIII .17. i 1 , '' 1 :j1 { 1I l II I J »i i l - 0 •-°r rAirAl MrAl it 2r -ir is-or III II 1 '1•-0r 4r-o• II ! 1 72 '4' ,•-6. 5-10' _ AM= IMOISMIIITAZIMIV 0MizAloha z 1 RIG 129 lAlz RIG 129 PLOT PLAN 6ME 2. ell. W. amen MEL ME 1nm m In si OF 1 • • TRANSMITTAL LETTER CHECKLIST WELL NAME 4...0 1414e, L•tGGt / 7% 3 3 PTD# -Q Development Service Exploratory Stratigraphic Test Non - Conventional Well (' / FIELD: 1 j u c-- r . POOL:..�?t" 411-e- L.f�t ' arc � - r KR.. L Circle Appropriate Letter ( Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new weilbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool STUMP LAKE, UNDEFINED GAS - 770500 Well Name: STUMPLK UNIT 41 -33RD Program DEV Well bore seg fl PTD #: 2090100 Company UNION OIL CO OF CALIFORNIA _ Initial Class/Type DEV / PEND.,_._ GeoArea 820 Unit 11970 On /Off Shore On Annular Disposal Administration 1 Permit fee attached NA - 12 Lease number appropriate Yes Entire wellbore will lie within ADL 058790 � 3 Unique well name and number Yes 4 Well located in a defined pool No STUMP LAKE, UNDEFINED GAS - 770500 5 Well located proper distance from drilling unit boundary Yes 5000' from unit boundary 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes Unitized Unocal lease 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date ; 12 Permit can be issued without administrative approval Yes SFD 1/26/2009 [13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA • 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre-produced injector: duration of pre - production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1.A)42.A -D) NA !18 Conductor string provided NA Conductor set in SLU 41 -33 (176 -086). Engineering 19 Surface casing protects all known USDWs NA Surface casing set in SLU 41 -33. 1 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing set in SLU 41 -33. 21 CMT vol adequate to tie -in long string to surf csg NA Intermediate casing set in SLU 41 -33. New intermediate liner will not be cemented to liner top. 22 CMT will cover all known productive horizons Yes 23 Casing designs adequate for C, T, B & permafrost Yes ,24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste to approved disposal well(s). 25 If a re- drill, has a 10 -403 for abandonment been approved Yes 308 -270 26 Adequate wellbore separation proposed - Yes Proximity analysis performed. Nearest segment is P &A portion of SLU 41 -33 and paths diverge. 27 If diverter required, does it meet regulations NA BOP stack will already be in place. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Maximum expected formation pressure 10.6 EMW. MW planned up to 11.1 ppg. TEM 2/4/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP calculated at 3679psi. 4000 psi BOP test proposed. ill if 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 133 Is presence of H2S gas probable No H2S is not reported in CI gas production. Rig equipped with sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures Yes Geology 36 Data presented on potential overpressure zones Yes max. expected reservoir pressure is 10.6 ppg EMW; will be drilled using up to 11.6 ppg mud. Appr Date 37 Seismic analysis of shallow gas zones NA SFD 1/26/2009 38 Seabed condition survey (if off- shore) _ _ - NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering P Date: Date Date Commissioner: Commissioner: C• -r �� °��'� I ,.... 44' 0 / I' • • Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • • Chevron 1 %0 Chevron North America E &P, Inc. SLU4 Stump Lake Unit r: Kenai Borough, Alaska `* Section -T14N -R8W, SM � Cook Inlet, Alaska • folamh .k 12, 2009 3 y `R - RT L - k Jeff McBeth — Logging Geologist Mainuddin Chowdhury — Logging Geologist Christina Medlyn — Logging Geologist Justin VanderBerg — Logging Geologist • E2I EPOCH ocii-ot v /9 �3s� S TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT AND CREW 3 1.1. EQUIPMENT SUMMARY 3 1.2. PERSONNEL 3 2. GENERAL WELL DETAILS 4 2.1. OBJECTIVES 4 2.2. WELL RESUME 4 2.3. HOLE DATA 4 3. GEOLOGICAL DATA 5 3.1. LITHOLOGY AND REMARKS 5 3.2. MUDLOG SUMMARY 7 3.3. SAMPLING PROGRAM AND DISTRIBUTION 17 • 4. DRILLING DATA 18 4.1. DAILY ACTIVITY SUMMARY 18 4.2. SURVEY RECORD 21 4.3. MUD RECORD 24 4.4. BIT RECORD 25 5. DAILY REPORTS 26 Enclosures: Formation Log 2" = 100' MD /TVD LWD Combo Log 2" = 100' MD /TVD Drilling Dynamics Log 2" = 100' MD/TVD Final Data CD's El EPOCH 'Chevron y • CHEVRON — SLU 41 -33RD 1 MUDLOGGING EQUIPMENT AND CREW 1.1. EQUIPMENT SUMMARY Parameter Equipment Type And Position Total Comments Downtime Electric Driven QGM Gas Trap Ditch Gas Mounted In Possum Belly; FID Total 9h 10m Hydrocarbon Analyzer And Chromatograph Rate of Penetration (ROP) Primary Draw works Belt Driven 0 0 Encoder On Drum Shaft (Rigwatch) Pump stroke counter Externally Mounted Magnetic Proximity 0 Occasionally spiky Sensor (Rigwatch) Down for Received hookload Hook load / Weight on bit (WOB) Proximity Crown Encoder (Rigwatch) whole well readings from Schlumberger Drill string torque Digital Signal From Top Drive 0 (Rigwatch ) Top drive rotary (RPM) Digital Signal From Top Drive 0 (Rigwatch) Standpipe Pressure Hydraulic Pressure Cell (Rigwatch) 0 Casing Pressure Hydraulic Pressure Cell (Rigwatch) 0 Mud flow in / out (MFI / MFO) MFI Derived From SPM / MFO From 0 • Flow Paddle (Rigwatch) Pit volumes Ball Float Pit Sensors In All Pits Except 0 pits 2 &b 3. Driller's work station Explosion Proof Touch Screen 0 Casing Pressure Hydraulic Pressure Cell Company man's work station Rigwatch 8 12h Due r n interruption Toolpusher's work station Rigwatch 8 12h Due r network interruption Geologist's work station None on location 0 Pitwatcher's work station Explosion Proof Touch Screen x Screen blew out due to circuit overload 1.2. PERSONNEL Unit Number / Type: ML012 - Steel Arctic Mudloggers Years Days Technician Days Sample Catchers Days Mainuddin Chowdhury 2 31 Steve Forrest 4 Jeff McBeth 0.7 37 Allen Williams 3 Justin VanderBerg 0.7 21 Christina Medlyn 1.5 37 El EPOCH 3 Chevron • CHEVRON — SLU 41 -33RD 2. GENERAL WELL DETAILS 2.1. OBJECTIVES The prior well SLU -41 -33 was drilled in 1978 within the same geological structure and produced 5.64 BCF of gas. The well was shut in due to sand and water production. The present side track SLU -41 -33 RD will develop several sands in the Sterling, Beluga and Tyonek formations. It will also develop bypassed pay that was not developed by the old well. The new information from this well will help to further evaluate the reservoir, lithology and other geologic information. 2.2. WELL RESUME Operator: Chevron Well Name: SLU 41 -33 RD Field and Pool: Stump Lake Unit State and Borough Kenai Borough, Alaska Company Representatives: Mike Leslie /Brad Rasch /Steve Lawrence Location: SEC 22, T14N, RO8W Elevation: — Ground, — RKB KB 45.1' Classification: Development Gas API #: 50- 283 - 20055 -01 • Permit #: 208 -184 AFE #: UWDAK- D9000 -DRL Rig Name / Type: Nabors 129 Primary Target: Gas Sands, Tyonek & Beluga Formations Primary Target Depth: 9391' MD / -7785' SS TVD Spud Date : -> Finish Date : -> 2/25/09 to 3/12/09 Total Depth: 10,160' MD; 9536.76' TVD Total Depth Formation: Below the Tyonek SL 92 -4 Mudlogging Company Epoch Well Services, Inc. (Canrig Drilling Technology Ltd.) MWD Company: Schlumberger Tools Run: Directional (motor); MWD (ImPulse); ADN (nuclear) Directional Drilling: Schlumberger Drilling Fluids Company: Halliburton 2.3. HOLE DATA Hole Maximum De T.D. Mud Deviation Shoe Depth Section MD TVD Formation weight (°inc) Casing MD TVD F.I.T. (PP9) 8.5" 6123' 5509' Lower 9.5 18.1 7" 6120' 5506' 15.0 Sterling 6.125" 10160' 9537' Tyonek 11.4 1.71 N.A. N.A. N.A. N.A. 410 [I EPOCH 4 {neuron I WO • CHEVRON - SLU 41 -33RD 3. GEOLOGICAL DATA 3.1. LITHOLOGY AND REMARKS FORMATION MD SSTVD (ft) (ft) Beluga Coal 6001 -5349 Lower Sterling Formation 6072 -5416 SL 56 -2 Sand top 6138 -5479 SL 56 -2 Sand base 6181 -5520 Beluga Formation 6379 -5713 SL 60 -1 Sand top 6556 -5888 SL 60 -1 Sand base 6593 -5924 SL 60 -7 Sand top 6607 -5938 SL 60 -7 Sand base 6621 -5953 SL 61 -3 Sand top 6683 -6015 • SL 61 -3 Sand base 6692 -6024 Beluga Conglomerates 6746 -6078 SL 66 -3 Sand top 7231 -6664 SL 66 -3 Sand base 7280 -6612 SL 66 -8 Sand top 7300 -6632 SL 66 -8 Sand base 7321 -6653 SL 67 -6 Sand top 7384 -6716 SL 67 -6 Sand base 7398 -6730 SL 69 -0 Sand top 7503 -6835 SL 69 -0 Sand base 7512 -6844 SL 70 -1 Shale 7658 -6991 El EPOCH 5 {neuron I WO 0 CHEVRON - SLU 41 -33RD LITHOLOGY AND REMARKS (CONTINUED) FORMATION MD SSTVD (ft) (ft) Tyonek Formation 8408 -7741 SL 77 -9 Sand top 8457 -7790 SL 77 -9 Sand base 8534 -7866 SL 80 -9 Sand top 8743 -8075 SL 80 -9 Sand base 8797 -8129 SL 81 -8 Sand top 8860 -8192 SL 81 -8 Sand base 8884 -8215 SL 90 -9 Sand top 9732 -9064 SL 90 -9 Sand base 9793 -9125 SL 91 -1 Sand top 9779 -9129 SL 91 -1 Sand base 9828 -9160 SL 92 -4 Sand top 9904 -9236 • SL 92 -4 Sand base 9931 -9263 Total Depth (TD) 10160 -9492 i EPOCH El EPOCH Chevron I OW • CHEVRON - SLU 41 -33RD 3.2. MUDLOG SUMMARY BELUGA COAL 6001' - 6071' MD (5349' - 5415' SSTVD) Drill Rate ( ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 204 40 116 121 15 72 Coal (60 %): Black to dark brownish black; hard; tough to brittle; platy cuttings habit; thin laminations visible on some; blocky to planar fracture; resinous to waxy luster; smooth to silty to gritty to abrasive texture; no visible degassing from samples. Tuffaceous Siltstone /Claystone (30 %): Clay is light bluish gray to light gray; clumpy to mushy; slightly firm; malleable; dull to earthy luster; smooth to clayey texture. Siltstone is light gray to light brownish gray; lumpy to clumpy; firm to friable; crumbly to malleable; earthy fracture; dull to earthy luster; gritty to silty texture. Sand and Sandstone (10 %): Clear, unconsolidated quartz grains; very fine to fine; well sorted; subrounded to rounded with moderate to high sphericity; no impact features visible on surfaces; occurring with trace amounts of conglomeritic sands. Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 6026 121 23545 6055 111 22199 - - - - - - 6075 105 21108 - - - - - - LOWER STERLING FORMATION 6072' - 6378' MD (5416' - 5712' SSTVD) Drill Rate (ft/hr Total Gas (units) Maximum Minimum Average Maximum Minimum Average 410 16 148 345 1 27 Tuffaceous Siltstone /Claystone (60 %): Medium light gray to medium gray; lumpy and curdy to very slightly firm; stiff to malleably; earthy to no visible fracture; dominantly nodular, spherical cuttings to occasionally flattened, nodular cuttings; dull, earthy luster with a smooth, clayey texture grading to silty; generally massive structure with some fine laminations and blebs of imbedded coal; claystone is well- hydrated; strongly cohesive; weakly adhesive; non - reactive to HCI; trace amounts of loose mica in sample. Sand /Conglomeritic Sandstone (20 %): Clear, unconsolidated quartz grains; very fine to fine; well sorted; subrounded to rounded with moderate to high sphericity; no impact features visible on surfaces; occurring with trace amounts of conglomeritic sands. [I EPOCH Chevron CHEVRON — SLU 41 -33RD Coal (10 %): Black with brownish hues; dense to tough tenacity; blocky to irregular fracture; tabular to occasional ly elongated cuttings; resinous to vitreous luster; sm ooth, matte texture with some conchoidal surface features visible; massive structure; visible outgassing. Minor ash tuff, shale and carbonaceous shale. Peaks Depth 6342 TG Cl 345 227101 C2 C3 iC4 nC4 iC5 nC5 - - - - - - Sands within the Lower Sterling Formation are individually summarized as follows: 56 -2 SAND 6138' - 6181' MD (5479'- 5520' SSTVD) Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 200 19 85 4* 1* 3* *gas equipment not fully operable Average Sandstone (20 %): Clear, unconsolidated quartz grains; very fine to fine; • well sorted; subrounded to rounded with moderate to high sphericity; no impact features visible • on surfaces; occurring with trace amounts of conglomeritic sands. Peaks Depth TG Cl C2 C3 iC4 nC4 iC5 nC5 L ( No MATpeaks ION detected — gas equipment not operating properly.) BELUGA FO 6379' - 8407' MD (5713' - 7740' SSTVD) Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 826 5 59 583 0 23 Tuffaceous Siltstone (50 %): medium to light gray to grayish brown; moderately hard to hard; tough and dense to stiff; earthy fracture; massive cutting habit; earthy luster; silty to abrasive to gritty texture; non - reactive to HCI ; trace amounts of loose mica in sample. Sand /Conglomeritic Sandstone (30 %): sandstones are gray to light gray and contain some white and smokey quartz along with some glauconitic clasts; grains are lower fine- to upper medium - grained with some coarse and a few pebble size fragments; moderate to poor sorting; angular to subangular to subround; highly variable sphericity; interbedded with thicker tuffaceous claystone /siltstone beds with tuff and fragments of black carbon shales: no visible porosity or permeability; no fluorescence or oil cut in samples. 41) [I EPOCH 8 Chevron • 11). CHEVRON — SLU 41 -33RD Tuffaceous Claystone (10 %): light to dark gray; varies from mushy gelatinous globules to slightly pasty clumps to moderately firm, occasionally brittle cuttings; crumbly to crunchy; hackly to no observable fracture; nodular to subwedgelike cuttings habit; dull earthy luster; smooth, clayey texture grading to silty; generally massive structure with frequent to common fine inclusions of coal; mushy claystone is well hydrated; high cohesion; I ow adhesion generally. Minor, locally abundant shale, carbonaceous shale, coal, and ash tuff: shales are very light gray to light gray to light brownish gray, friable to moderately hard to hard, with platy cuttings habit, dull luster, and smooth to silty texture; carbonaceous s hales are brownish black to grayish brown to dark reddish brown, moderately hard to hard, dense to crun chy to crumbly, with an earthy lusterand a silty to gritty to abrasive texture; coals are either massive or splintery, black to brownish black with a resinous to vitreous luster and a smooth matte texture, and com mon outgassing on surfaces; ash tuffs are highly devitrified, bluish white to light gray, soft, pasty to mushy, amorphous clumps of clay with a dull luster and moderate adhesion. Peaks Depth TG C1 C2 C3 iC4 nC4 - - - - - - - iC5 nC5 6395 121 70315 - - - - - 6422 72 27844 61 36340 - - - - 6461 - - - - - 6561 40 24253 - - - - - 6651 40 18274 - - - - 7068 30 22383 - - - - 7166 79 54449 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7376 57 12577 7397 51 11203 - - 7443 330 606664 - - - - - - - - - - - - - - - - - - - - 7452 147 387788 - - 7471 76 47776 - - 7499 72 38892 - - 7521 166 130744 - - BELUGA FORMATION Peaks (continued) 7538 84 41871 - - 7563 144 82958 - - 7591 127 73058 - - - 7635 583 460221 - - 7671 165 108580 - - 7686 164 123824 - - 7710 158 107977 - - 7728 67 44729 - - - - - - - - - - - - - - 7891 87 38741 - - 7951 132 90372 - 7999 109 74595 - 8026 107 73001 - 8086 93 63758 - - 8142 107 84655 - - - - 8193 124 97691 - - - - - - [1 EPOCH 9 Chevron I WO IWO • CHEVRON - SLU 41 -33RD 8331 50 10079 - - - - - - 8394 66 136957 - - - - - - Sands and other subdivisions of the Beluga Formation are individually summarized as follows: 60 -1 SAND 6556' - 6593' MD (5888' - 5924' SSTVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 253 9 93 39 13 20 Sandstone: light gray to very light gray to translucent with greenstone and smokey quartz present; upper fine to upper medium grains with some coarse to pebble size fragments; moderate sorting; angular to subangu lar to subrounded; low to moderate sphericity; silica cement; no fluorescence or oil cut in sample. Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 6561 40 24253 - - - - - • 60 -7 SAND 6607' - 6621' MD (5938' - 5953' SSTVD) Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 183 29 84 17 11 17 Sandstone: light gray to very light gray to translucent with greenstone and smokey quartz present; upper fine to upper medium grains with some coarse to pebble size fragments; moderate sorting; angular to subangu lar to subrounded; low to moderate sphericity; silica cement; no fluorescence or oil cut in sample. Peaks Depth TG C1 6683' - 6692' MD (6015' - 6024' C2 C3 iC4 nC4 iC5 nC5 (no significant peaks) 61 -3 SAND SSTVD) Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 141 81 120 7 7 7 El L7 10 Chevron • CHEVRON - SLU 41 -33RD Sandstone: light gray to very light gray to translucent with greenstone and smokey quartz present; upper fine to upper medium grains with some coarse to pebble size fragments; moderate sorting; angular to subangular to subrounded; low to moderate sphericity; silica cement; no fluorescence or oil cut in sample. Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 ( significant peaks) BELUGA CONGLOMERATES 6746' - 7230' MD (6078' - 6563' SS no TVD) Drill Rate (ft/hr Total Gas (units) Maximum Minimum Average Maximum Minimum Average 151 7 51 79 1 10 Conglomeritic sandstone /sandstone: gray to light gray with whites and greenstone; pebble -sized to upper medium- to lower fine- grained; angular to subangular grains in sandstone and subangular to subrounded grains in conglomeritic sandstone; poor to moderate sorting; impacted to pitted surface textures; silicic cement; greenstone sand consists of green to dark green grains of glauconite; poor visible porosity and permeability; no fluorescence nor oil cut. • Peaks Depth TG Cl 22383 C2 C3 iC4 nC4 iC5 nC5 7068 30 - - - - - 7166 79 54449 - - - - - - 66 -3 SAND 7231' - 7280' MD (6564' - 6612' SSTVD) Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 52 5 35 32 6 13 Conglomeritic sand: black and green grains dominate, along with quartzite; ranging from fine- to coarse - grained with occasional gravel sized grains; very poor to poor sorting; angular to subrounded; low to moderate sphericity; angular to sub angular in sand and round to subrounded in conglomeritic sand; interbedded with thicker tuffaceous claystone /siltstone beds with tuff and fragments of black carbon shales: no visible porosity or permeability; no fluorescence nor oil cut in sam ple. Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 (no significant peaks) 11 [I EPOCH • CHEVRON - SLU 41 -33RD 66 -8 SAND 7300' - 7321' MD (6632' - 6653' SS TVD) Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum m Minimum Average 59 16 38 32 8 16 Sand: light gray with translucent grains; lower fine- to lower medium - grained; moderate sorting; subrounded to subangular; moderate sphericity; impact feature and pitting on grain surf aces; loose unconsolidated quartz grains; occasionally frosted; poor visible permeability and porosity. Peaks Depth 67 -6 SAND TG C1 C2 C3 iC4 nC4 iC5 nC5 ( significant peaks) 7384' - 7398' MD (6716' - 6730' SS TVD) Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 79 39 65 51 3 18 41° Sand: light gray with translucent grains; lower fine- to lower medium - grained; moderate sorting; subrounded to subangular; moderate sphericity; impact feature and pitting on grain surf aces; loose unconsolidated quartz grains; occasionally frosted; poor visible permeability and porosity. Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 7397 51 11203 - - - - - - 70 -1 SHALE 7658' - 8407' MD (6991' - 7740' SS TVD) Drill Rate (ft/hr Total Gas (units) Maximum Minimum Average Maximum Minimum Average 119 6 48 165 0 27 Carbonaceous shale: brownish black to dark reddish brown to black; friable to moderately hard; crunchy to crumbly; very fissile; tabular to platy cuttings habit; thin laminations; earthy luster; gritty to smooth texture. Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 7671 165 108580 - - - - - - 7686 164 123824 - - - - - - Ii EPOCH 12 chevron � IWO • CHEVRON - SLU 41 -33RD 7710 158 107977 - - - - - 7728 67 44729 - - - - - - 7891 87 38741 - - - - - - 7951 132 90372 - - - - - - 7999 109 74595 - - - - - 8026 107 73001 - - - - - - 8086 93 63758 - - - - - - 8142 107 84655 - - - - - - 8193 124 97691 - - - - - - 8331 50 10079 - - - - - - 8394 66 136957 - - - - - - TYONEK FORMATION 8408' - 10160' MD (7741' - 9492' SS TVD) Drill Rate (ft/hr Total Gas (units) Maximum Minimum Average Maximum Minimum Average 192 5 38 437 0 30 Tuffaceous Siltstone (50 %): pale orange or brown to light brownish gray gradational tuffaceous silt and clay with interbedded fine to very fine sand; no visible grain support; poorly consolidated; moderately hard to soft, comes apart easily; consistency varies with clay content; • amorphous, slightly blocky habit; earthy fracture; dull, earthy luster; colloidal to ashy texture; many small inclusions of varying color throughout cuttings; sparse ash tuff displays bright green fluorescence Sand (30 %): mostly light gray loose sand with some greenstone grains; lower fine- to upper medium - grained with occasional coarse grains; variably poor to well sorted; subangular to subrounded; high sphericity; coarse grains are angular; frosted grain surfaces and chipped grains; 90% quartz with 10% lithic material; some friable but intact matrix - supported tuffaceous sandstone cuttings with depth; slighty calcitic; poor to fair visible porosity and permeability; interbedded with tuffaceous claystones /siltstones with small fragments of black carbonaceous shales; trace amounts of small pyrite nodules; no fluorescence or oil cut in samples. Tuffaceous Claystone (10 %): light to medium gray but commonly brown; lumpy to flaky cuttings habit; mushy to pasty overall; intact cuttings are soft to moderately firm; irregular amorphous earthy fracture; dull, earthy luster; clayey to silty texture; generally no visible structure with rare imbedded carbonaceous material. Carbonaceous S hale and Coal (10 %): brownish gray to black; dense to tough; platy to wedgelike cuttings habit; brittle to crumbly; splintery to planar fracture; blocky fracture in coals; earthy to resinous luster; smooth matte texture; generally massive structure with moderate to good fissility; darker laminations and blebs of carbonaceous material common; interbedded with tuffaceous silt/clay; some outgassing visible in sample; coals display very weak fluorescence. Peaks Depth TG C1 C2 C3 iC4 [I EPOCH nC4 iC5 nC5 8553 100 59464 - - - - - - • 13 • CHEVRON — SLU 41 -33RD 8665 67 46238 - - - - - - 8679 76 54204 - - - - - - 8723 113 72933 - - - - - - 8887 140 27680 125 - - - - - 8918 51 10132 - - - - - - 8945 98 18866 - - - - - - 8965 66 12851 - - - - - - 9019 128 24663 - - - - - - 9079 254 169482 - - - - - - 9161 45 29012 - - - - - - 9269 78 15003 - - - - - - 9359 129 25622 - - - - - - 9386 164 31993 - - - - - - TYONEK FORMATION Peaks (continued) Depth TG C1 C2 C3 iC4 nC4 105 nC5 9434 150 98149 - - - - - - 9493 92 61105 - - - - - - 9548 173 121608 - - - - - - 9669 367 72658 - - - - - - 9722 129 24568 - - - - - - 46° 9749 206 39798 - - - - - - 9931 56 10916 10008 438 302240 - - - - - - 10035 264 132017 10082 236 167008 - - Chevron - - - - - - 10096 211 142439 - - - - - - Sands within the Tyonek Formation are individually summarized as follows: 77 -9 SAND 8457' - 8534' MD (7866' - 7790' SS TVD) Drill Rate (ft/hr Total Gas (units - Maximum Minimum Average Maximum Minimum Average 116 12 42 38 4 18 Sand: light gray to yellowish gray with some translucent grains and greenst ones; lower fine- to lower medium - grained with occasional coarse grains; well sorted; subang ular to subrounded; moderately high sphericity; mostly loose unconsolidated sand, at lower depths some cementing is visible, slighty calcitic; moderate to good visible porosity and permeability. Peaks Depth TG C1 C2 C3 nC4 iC5 nC5 9493 92 61105 - - - - - - El EPOCH iC4 14 • CHE VRON — SLU 41 -33RD 80 -9 SAND 8743' - 8797' MD (8075' - 8129' SSTVD Drill Rate (ft/hr Maximum Minimum Average Chevron Maximum Total Gas (units Minimum Average 35 7 18 30 2 16 Sand: medium gray to very light gray with some white grains; grain sizes range from upper medium- to lower fine - grained; angular to subangular, and occasionally subrounded in small parts of sandstones; moderately sorted; frosted and chipped surface textures; mature nature, with non- to very slightly silicic cement; interstitial clayey material, and loosely bound overall by tuffaceous silt and clays; interbedded with tuffaceous claystones /siltstones with small fragments of black carbonaceous shales; 90% quartz with 10% lithic material; clasts of greenstones, pyrite, and argillite are scattered; fair estimated porosity and permeability; no fluorescence or oil cut. Peaks Depth TG C1 C2 C3 iC4 nC4 105 nC5 9749 206 39798 - - - - - - 81 -8 SAND 8860' - 8884' MD (8192' - 8215' SSTVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 67 23 41 50 5 19 Sand: light gray to very light gray; grain sizes range from upper medium- to lower fine - grained with a slight decrease in g rain size with depth; subangular to subrounded; well developed sphericity; moderately sorted; chipped grains and surface impact features; mature nature; unconsolidated hard siltstone with claystone clustered within interbedded sections of sand; composed of 90% crystalline sand with 10% lithic material; interbedded siltstone with thinner coal and black carbonaceous shales; poor to fair estimated porosity and permeability; no fluorescence or oil cut. Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 8887 140 27680 125 - - - - - 90 -9 SAND 9732' - 9793' MD (9064' - 9125' SSTVD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 45 127 10 59 206 18 [1 EPOCH 15 Chevron N INO • CHEVRON - SLU 41 -33RD Sand /Sandstone: translucent light gray to medium gray quartz sand with scattered siliceous mudstone; clast size ranges from lower coarse- to lower medium - grained; rounded to subrounded; moderate to high sphericity; siliceous mudstone grains are dark gray; coarser to fine- grained sand range; sands are moderately to poorly sorted; interbedded tuffaceous claystone and siltstone with thin coal /carbonaceous shale; composed of mostly translucent quartz and minor lithic material; fair estimated porosity and permeability; no fluorescence or oil cut. Peaks Depth TG C1 C2 C3 1C4 nC4 iC5 nC5 9749 206 39798 - - - - - - 91 -1 SAND 9797' - 9828' MD (9129' - 9160' SSTVD) Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 120 24 88 54 17 29 Sand /Sandstone: translucent light gray to medium gray quartz sand with scattered siliceous mudstone; clast size ranges from lower coarse- to lower medium - grained; rounded to subrounded; moderate to high sphericity; siliceous mudstone grains are dark gray; coarser to fine- grained sand range; sands are moderately to poorly sorted; interbedded tuffaceous claystone and siltstone with thin coal /carbonaceous shale; composed of mostly translucent quartz and minor lithic material; fair estimated porosity and permeability; no fluorescence or oil cut. Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 (no significant peaks) 92 -4 SAND 9904' - 9931' MD (9236' - 9263' SSTVD) Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 129 27 70 55 15 28 Sand: clear and frosted quartz with few lithics; very fine- to fine - grained with scattered medium grains; moderately to well sorted; subrounded to rounded; overall high sphericity but ranging from moderate to very high; uncommon lithic grains of volcanic origin. Peaks Depth TG C1 C2 C3 iC4 nC4 iC5 nC5 9931 56 10916 - - - - - - [I EPOCH 16 Chevron • CHEVRON - SLU 41 -33RD 3.3. SAMPLING PROGRAM AND DISTRIBUTION Set Type and Purpose Interval Frequency Distribution 2868- 10160' 30' Chevron Washed and dried 909 West 9 Avenue A Contained in four (4) 8490 -8530' Anchorage, AK 99501 Boxes. 8850 -8910' 10' Attn: Debra Oudean and 9740 - 10,000' Francisco Castro 2868- 10160' 30' Chevron Washed and dried 909 West 9 Avenue B Contained in four (4) 8490 -8530' Anchorage, AK 99501 Boxes 8850 -8910' 10' Attn: Debra Oudean and 9740 - 10,000' Francisco Castro Chevron Unwashed and wet. 909 West 9'" Avenue C Box#1 2868 -6113' 30' Anchorage, AK 99501 Attn: Debra Oudean and Francisco Castro • 6113-10160' 30' Chevron Unwashed and wet. 8490 -8530' 909 West 9 Avenue C Box 8850 -8910' 10' Anchorage, AK 99501 9740 - 10,000' Attn: Debra Oudean and Francisco Castro El EPOCH 17 Chevron IWO • CHEVRON - SLU 41 -33RD 4. DRILLING DATA 4.1. DAILY ACTIVITY SUMMARY Feb. 20, 2009: Test BOPs on 4" DP. Repaired top drive, but test f ailed. Begin assembly of milling BHA. Feb. 21, 2009: Continue to test BOP; pick up milling assembly and trip in hole. Tag bottom and displace with 9.8% KCL mud; circulate hole clean. Pull out of hole to run packer. Set packer and test casing to 2000 psi. Begin lifting BOPs to change well head. Feb. 22, 2009: Rig down BOPs to remove well head. Lifted stack and pull well head off. Re- assemble BOP stack and retest lines. Fix top drive and test . Pick up whipstock and gyro tools and run in hole with whipstock. Running in hole at midnight. Feb. 23, 2009: Assemble milling BHA and whipstock and run in hole. Set whipstock at 2900'. Orient whipstock to 317 degrees azimuth and set in place. Verify orientation with gyro. Circulate and begin milling window through casing. Top of window at 2867' and bottom of window at 2884'. Circulate cutti ngs out, then trip out to lay down milling assembly. Feb. 24, 2009: Began making up BHA but top drive and saver sub need ed repairs. Picked up and made up BHA and ran in hole with drill pipe to 2843'. Shallow hole test conducted. Pulled out of hole to rack back the drill pipe, then began running in the hole while making up joints. • Feb. 25, 2009: Continue tripping in hole while picking up and making up drill pipe. Circulate and condition mud. Run wireline gyro survey. Continued drilling in intervals and stopping for wireline gyro surveys. Taking gyro survey at midnight. Feb. 26, 2009: Wireline survey ran gyro. Drill and slide to 3706'; pumped sweep at 3680'. Saw a 30% cuttings increase. Drilling fault 3940' - 3958'; reamed twice and string came slick. Drilled ahead to 4531'. Pumped high viscosity sweep at 4210' with a 10% increase in cuttings. Serviced rig #1 mud pump. Drilled ahead, circulated and conditioned mud. Pumped another high viscosity sweep at 4563'. Made a short trip to inside milled casing window. Encountered a tight spot from 4006' - 4016'. Serviced the top drive. Tripped in the hole to 4466'; washed to bottom. Drilled ahead to 5251'. Feb. 27, 2009: Drill and slide from 5251' to 5680'. Experienced 20k over -pull from 5533' to 5575'; worked pipe then it came slick. Conducted a flow check each connection. Drilled from 5680' to 6075'. Pumped high viscosity sweep at 5730' and received a 15% increase in cuttings. Circulated and conditioned mud due to MWD tool not tracking depth. Drilled ahead to 6123', casing point. Pumped high viscous sweep and circulated bottoms up . Tripped out of the hole to 4468'; drill string pulled tight from 6110' to 6160' — 10k over. Tripped in the hole to 5992'; dropped a carbide and washed and reamed from 6089' to 6123'. Circulated and conditioned mud. Pumped high viscous sweep with marker, spotted baratrol pill. Tripped in hole 6123' — 5231'. Strapped out and drill string pulled tight from 4320' - 4280' with 15k over -pull. Feb. 28, 2009: Pull out of hole for casing point; lay down BHA and collars. Clean pits and test BOP. Ran casing then ran in the hole; had to ream from 6109' - 6120'. Circulating and conditioning mud at midnight. • [l EPOCH 18 C IWO CHEVRON - SLU 41 -33RD Mar. 1, 2009: Continue circul ating and conditioning m ud while waiting on cement head. Cement; nipple up; and test BOP s. Mar. 2, 2009: Continue testing of BOPs and then begin pic king up BHA. Mar. 3, 2009: Continue assembling BHA and picking up drill pipe. Tripping and reaming to bottom; pressure up to test casing shoe. Displace hole and build volum e. Drilled through cement and performed Formation Integrity Test. Resumed drilling. Mar. 4, 2009: Drilled ahead and ran a high- viscosity sweep at 7026' resulting in a 100% increase in cuttings. Mar. 5, 2009: Continue drilling ahead; pum ped another high- viscosity sweep at 7717' with 400- 500% cuttings increase. Mar. 6, 2009: Drilled to 8359', just above the Tyonek Coal. Circulated bottoms -up, then began a wiper trip to the shoe. Mar. 7, 2009: Continue tripping to shoe for wiper trip. Run back to bottom and circulate out gas; drill ahead. Mar. 8, 2009: Drilled to 8721' then pulled out of hole for new bit; bit was severely damaged. Changed BHA to replace steerable m otor for a straight motor. Ran in the hole and had to ream • from 8665' to bottom. Mar. 9, 2009: Drilled ahead. Ran the de- silter for the whole day to help with removal of fine solids from mud. Checked shakers at each connection for holes in screens. Mar. 10, 2009: Continue drilling ahead with slow ROP. Pumped a high viscosity sweep with nut plug and weighted up the m ud to 11.1. Mar. 11, 2009: Drilled ahead almost to TD. Pumped a high- viscosity, weighted sweep with nut plug at 9730' and received a 150% increase in cuttings. Sweep came back 44 bbls late indicating a 56% washout. Mar. 12, 2009: Reached TD of 10160' at lam. Pumped another high- viscosity, weighted, nut - plug sweep at TD with an 80% increase in cuttings. Short tripped up to 8569' then w ashed and reamed back to bottom. Conducted flow testing and swab testing. Pumped out to 9237' and had differential sticking at connections. Mar. 13, 2009: Obtaining high gas spikes; circulate on bottom to weight up mud to 11.6. Gas greatly subsided. Pull out of hole and lay down the BHA and remove source from ADN tool. Rigging up for wireline at midnight. Mar. 14, 2009: Made attempts to run wireline but wireline could not get below —6200'. Decided to trip in for a clean out run. Encountered tight spot at 9700' ; worked through tight spot. Weighted up mud from 11.6 to 11.9. Continue ream ing to bottom; reaming at midnight. El EPOCH 19 { CHEVRON - SLU 41 -33RD Mar. 15, 2009: Continue running to bottom and circulating to get even MW throughout system. Pumped high viscosity sweep with nut plug marker; sweep was late returning indicating significant washout. While back - reaming, sweeps were pumped at 9490', 8633' and 6430'. Experiencing swabbing while pulling out of the hole, so had to continue circulat ing. Mar. 16, 2009: Continue back reaming slowly out of the hole. Once out, begin rigging w ireline for a -logs. Wireline attempt unsuccessful, so tested BOPs and rigged up to run liner. Began running liner; running liner at midnight. Mar. 17, 2009: Continue and finish running liner and rig up to run drill pipe to lower liner into open hole. Stop at 6048' to circulate and even out M W. Resume running in with liner and drill pipe to 9123'; liner would not pass beyond this point. After hours of attempting to break through, decision was made to cement it in place. Rigging up to cem ent at midnight. Mar. 18, 2009: Complete rig -up for cement and pump cement. Circulate with water. Mudloggers released; partial rig -down conducted by mudloggers leaving RigWatch running for the rig. El EPOCH 20 S 0 • 4.2. SURVEY RECORD Measured Inclination Azimuth TVD Vertical Course length DLS Depth (ft) (deg) (deg) (ft) Section (ft) +NS- +EW- INCR VS (ft) (deg1100ft) 2900.00 2.13 22.96 2899.69 _ -18.53 -28.95 -5.3 100.0 2.48 3000.00 5.09 16.65 2999.48 -15.3 -22.99 -3.3 100.0 2.98 3100.00 6.31 0.83 3098.99 -8.78 -13.24 -1.95 100.0 1.98 3200.00 9.96 345.6 3197.98 3.1 0.63 -4.07 100.0 4.21 3300.00 12.67 335.97 3296.03 21.37 19.03 -10.64 100.0 3.29 3400.00 15.98 327.67 3392.92 45.51 40.69 -22.47 100.0 3.89 3500.00 19.2 316.65 3488.26 75.58 64.29 -41.13 100.0 4.62 3585.00 23.68 311.73 3567.36 106.47 85.83 -63.48 85.0 5.68 3623.44 24.47 313.95 3602.46 122.05 96.49 -74.97 38.44 3.13 3717.18 29.54 315.01 3685.95 164.44 126.33 - 105.31 93.74 5.43 3811.74 34.67 313.94 3766.03 214.50 161.5 - 141.18 94.56 5.46 3907.95 37.94 314.10 3843.55 271.20 _ 201.08 - 182.13 96.21 3.40 4002.65 42.3 314.58 3915.95 331.98 243.73 - 225.76 94.7 4.62 4097.16 46.71 317.68 3983.34 398.09 291.51 - 271.60 94.51 5.20 4192.25 47.46 318.72 4048.09 467.71 343.43 - 318.01 95.09 1.12 4288.96 47.55 318.75 4113.42 539.02 397.09 - .65.04 96.71 0.10 4382.80 47.92 318.43 4176.53 608.46 449.11 - 410.97 93.84 0.47 4479.21 48.63 318.45 4240.70 680.40 502.95 - 458.71 96.41 0.74 4575.04 49.18 318.40 4303.69 752.61 556.98 - 506.63 95.83 0.58 4669.85 49.48 318.48 4365.48 824.51 610.79 - 554.34 94.81 0.32 4766.51 48.34 319.68 4429.01 897.36 _ 665.83 - 602.06 96.66 1.51 4863.90 48.97 319.98 4493.34 970.47 721.70 - 649.22 97.39 0.69 4957.36 48.42 320.66 _ 4555.03 1040.67 775.73 - 694.05 93.46 0.80 5052.56 47.07 321.17 4619.05 1111.10 830.42 - 738.48 95.20 1.47 5146.60 46.96 320.54 4683.16 _ 1179.87 883.77 - 781.90 94.04 0.50 5243.76 44.47 322.54 4751.00 1249.37 938.21 - 825.18 97.16 2.96 El EPOCH s • • Chevron CHEVRON - SLU 41 -33RD SURVEY RECORD (CONTINUED) Measured Inclination Azimuth TVD Vertical Course length DLS Depth (ft) (deg) (deg) (ft) Section (ft) +NS- _ +EW- INCR VS (ft) (deg /100ft) 5339.15 41.71 323.31 4820.66 1314.40 _ 990.19 - 864.47 95.39 2.95 5434.02 38.22 322.68 4893.36 1375.21 1038.85 - 901.13 94.87 3.70 5527.65 34.02 320.98 4968.98 1430.33 1082.26 - 935.19 93.63 4.61 5623.05 30.11 320.28 5049.81 1480.95 1121.41 _ - 967.30 95.40 4.12 5718.36 26.46 319.57 5133.72 1526.10 1155.97 - 996.36 95.31 3.85 5813.51 25.31 321.10 5219.33 1567.63 1187.94 - 1022.88 95.15 1.40 5908.54 21.35 322.81 5306.57 1605.22 1217.54 - 1045.10 95.03 4.23 6005.22 18.35 317.55 5397.50 1638.01 1242.80 _ - 1067.02 96.68 3.61 6038.20 18.10 315.95 5428.83 1648.31 1250.31 _ - 1074.08 32.98 1.70 6133.05 18.47 318.92 5518.89 1678.04 1272.23 - 1094.20 94.85 1.06 6227.71 16.12 317.69 5609.27 1706.18 1293.25 - 1112.90 94.66 2.51 6321.90 11.37 324.61 5700.74 1728.51 1310.50 - 1127.09 94.19 5.33 6416.69 8.02 330.52 5794.16 1744.31 1323.88 - 1135.76 94.79 3.68 6511.98 3.57 321.92 5888.94 1753.80 1332.01 - 1140.86 95.29 4.75 6607.21 0.15 46.80 5984.11 1756.77 1334.43 - 1142.60 95.23 3.74 6701.57 0.10 98.45 6078.47 1756.71 1334.50 - 1142.43 94.36 0.12 6794.53 0.12 1.41 6171.43 1756.72 1334.58 - 1142.35 92.96 0.18 6892.06 0.10 200.72 6268.96 1756.75 1334.61 - 1142.37 97.53 0.22 6988.14 0.08 15.68 6365.04 1756.75 1334.59 - 1142.39 96.08 0.19 7085.86 0.10 2.08 6462.76 1756.85 _ 1334.74 _ - 1142.36 97.72 0.03 7180.90 0.11 129.28 6557.80 1756.82 1334.77 - 1142.29 95.04 0.20 7277.55 0.15 123.67 6654.45 1756.61 1334.64 - 1142.11 96.65 0.04 7373.18 0.05 45.53 6750.08 _ 1756.49 1334.62 - 1141.96 95.63 0.16 7468.34 0.10 263.37 6845.24 1756.55 1334.65 - 1142.00 95.16 0.18 7564.05 0.15 346.52 6940.95 1756.70 1334.77 - 1142.11 95.71 0.18 7659.85 0.12 145.17 7036.75 1756.72 1334.81 - 1142.08 95.80 0.28 El EPOCH 22 • • • chi, IOW CHEVRON - SLU 41 -33RD SURVEY RECORD (CONTINUED) Measured Inclination Azimuth TVD Vertical Course length DLS Depth (ft) (deg) (deg) (ft) Section (ft) +NS- +EW- INCR VS (ft) (deg /100ft) 7754.24 0.11 110.77 7131.14 1756.54 _ 1334.69 - 1141.94 94.39 0.07 7850.30 0.12 277.32 7227.20 1756.53 1334.67 - 1141.95 96.06 0.24 7945.78 0.05 281.78 7322.68 1756.64 1334.69 - 1142.69 95.48 0.07 8039.30 0.10 359.52 7416.20 _ 1756.73 1334.78 - 1142.13 93.52 0.11 8136.24 0.12 97.07 7513.14 1756.72 1334.86 - 1142.03 96.94 0.17 8229.04 0.08 76.35 7605.94 1756.62 1334.86 - 1141.87 92.80 0.06 8323.29 0.08 8.04 7700.19 1756.64 1334.94 - 1141.80 94.25 0.10 8421.83 0.08 84.17 7798.73 1756.64 1335.01 - 1141.72 98.54 0.10 8516.81 0.03 291.54 7893.71 1756.63 1335.03 - 1141.68 94.98 0.11 8611.58 0.05 69.47 7988.48 1756.63 1335.05 - 1141.66 94.77 0.08 8705.81 0.14 35.53 8082.71 _ 1756.65 1335.16 - 1141.56 94.23 0.11 8801.92 0.05 222.28 8178.82 _ 1756.67 1335.23 - 1141.52 96.11 0.20 8896.51 0.52 139.69 8273.41 1756.24 1334.87 - 1141.27 94.59 0.55 8991.25 0.27 134.37 8368.15 1755.58 1334.39 - 1140.83 94.74 0.27 9088.11 0.73 141.21 8465.00 1754.74 1333.74 - 1140.28 96.86 0.48 9182.12 0.78 183.25 8559.01 1753.68 1332.64 - 1139.94 94.01 0.58 9276.95 0.71 176.45 8653.83 1752.75 1331.41 - 1139.94 94.83 0.12 9374.96 0.83 171.96 8751.83 1751.66 1330.10 - 1139.81 98.01 0.14 9468.94 0.51 198.62 8845.80 1750.88 1329.03 - 1139.84 93.98 0.47 9565.77 0.17 138.52 8942.63 1750.51 1328.51 - 1139.89 96.83 0.46 9659.24 0.17 195.25 9036.10 1750.29 1328.28 - 1139.83 93.47 0.17 9753.63 0.44 133.78 _ 9130.49 1749.86 _ 1327.89 - 1139.61 94.39 0.41 9848.21 0.65 120.79 9225.07 1748.99 1327.36 - 1138.88 94.58 0.26 9943.08 1.44 122.27 9319.92 1747.34 _ 1326.45 - 1137.41 94.87 0.83 10038.38 1.48 139.82 9415.19 1744.96 1324.87 - 1135.61 95.30 0.47 10104.53 1.71 156.28 9481.31 1743.16 1323.32 - 1134.66 66.15 0.77 Ii EPOCH 23 • • • chevron ONO CHEVRON - SLU 41 -33RD 4.3. MUD RECORD Contractor: Baroid Mud Type: LSND Mud DATE DEPTH MW VIS PV YP GELS HTHP AP SOLIDS OIL/WATER SAND MBT pH ChI Ca 2/20/09 0 9.8 62 13 24 9/21/- 0 2/- 6.4 -/92.0 0.30 12.5 9.8 20000 400 2/21/09 0 9.8 63 11 26 7/12/- 0 2/- 6.8 0.5/91.0 0.30 12.5 9.8 21000 400 2/22/09 0 9.7 68 13 24 8/18/- 0 2/- 7.8 0.5/90.0 0.30 12.0 9.6 21000 400 2/23/09 2884' 10.0 59 18 21 9/21/- 0 1/- 8.7 -/89.0 -- 10.0 9.1 29000 240 2/24/09 2884' 9.3 58 13 23 8/14/- 0 1/- 4.6 -/93.0 0.10 2.5 9.0 29000 400 2/25/09 3601' 9.2 51 11 22 7/12/18 0 1/- 4.7 -/93.5 0.12 5.0 9.0 22000 400 2/26/09 5164' 9.2 46 12 22 6/10/14 0 1/- 4.0 -/93.5 0.50 5.0 9.1 31000 520 2/27/09 6123' 9.4 45 13 22 6/8/14 0 1/- 5.5 -/92.0 0.50 6.2 8.5 31000 520 2/28/09 6123' 9.2 49 8 22 5/7/15 0 1/- 5.8 -/93.0 0.25 6.2 9.4 28000 320 3/1/09 6123' 9.5 48 11 24 6/8/14 0 1/- 6.6 -/91.2 0.50 6.0 8.8 28000 520 3/2/09 6123' 9.5 49 8 20 6/8/12 0 1/- 6.2 -/91.5 0.50 6.2 8.5 27000 680 3/3/09 6123' 9.4 50 7 17 5/8/11 0 1/- 5.9 -/92.0 0.50 6.2 8.4 26500 600 3/4/09 7122' 10.0 46 9 22 5/8/15 0 1/- 7.6 -/90.0 0.25 6.5 9.1 30000 680 3/5/09 7804' 10.1 49 16 22 5/10/16 0 1/- 8.7 1.0/88.0 0.25 6.2 9.2 30000 220 3/6/09 8359' 10.4 49 15 25 6/19/24 0 1/- 9.2 1.5/87.0 0.25 7.5 8.4 30000 240 3/7/09 8721' 10.9 49 14 25 6/15/19 0 1/- 12.4 1.0/84.5 0.25 7.5 9.0 29000 260 3/8/09 8721' 10.9 51 16 19 5/14/19 0 1/- 12.3 1.0/84.5 0.25 7.5 9.5 29500 260 3/9/09 8922' 10.9 53 19 24 7/16/22 0 1/- 13.0 0.5/84.5 0.25 7.5 9.0 27000 240 Li EPOCH 24 0 • 0 chevron IWO CHEVRON - SLU 41 -33RD MUD RECORD (CONTINUED) DATE DEPTH MW VIS PV YP GELS HTHP AP SOLIDS OIL/WATER SAND MBT pH ChI Ca 3/10/09 9412' 11.1 46 16 18 5/12/21 0 1/- 13.4 1.0/83.5 0.25 7.5 9.3 29000 200 3/11/09 10045' 11.4 48 17 18 5/12/16 0 1/- 13.2 1.0/84.0 0.20 7.0 8.6 25000 260 3/12/09 10160' 11.6 49 18 20 6/16/19 0 1/- 13.7 1.0/83.5 0.20 7.5 9.0 25000 260 3/13/09 10160' 11.6 54 18 18 6/14/18 0 1/- 13.8 1.0/83.4 0.20 7.5 9.2 24000 260 3/14/09 10160' 11.8 56 20 18 7/18/- 0 2- 14.8 0.5/83.0 0.50 10.0 8.6 24000 240 3/15/09 10160' 11.9 64 22 23 8/18/- 0 2/- 15.3 1.0/82.0 0.50 10.0 8.90 24000 240 3/16/09 10160' 11.8 60 18 20 7/16/21 0 1/- 15.3 1.0/82.0 0.50 10.0 8.6 24000 240 3/17/09 10160' 11.7 57 18 18 6/16/21 0 1/- 15.4 1.0/82.0 0.25 10.0 8.2 22000 240 4.4. BIT RECORD BIT NO SIZE MAKE TYPE S/N JETS/TFA IN OUT FEET HOURS AVE WOB CONDITION 1 8.5" HTC MXL -09DX 6054051 3x16 2908' 6123' 3215' 25.8 124.5 17 3- 2- LT- A- E- 3 -NO -TD 2 6.125" HYC MSX513M -A1 B 54833 3x9, 2x10 6123' 8722' 2599' 64.9 40.0 12 3- 4- CT- A- X- I -PN -PR 3 6.125" HTC HCM505ZX 7010032 4x10, 1x12 8722' 10160' 1438' 58.5 24.56 18 3 - 2 - CT N - X - 1 - CT - TD Ell EPOCH 25 Cnevroe • CHEVRON — SLU 41 -33RD 5. DAILY REPORTS 0 • 26 El EPOCH Daily Report Chevron • DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR Don Fowler /Brad Rasch DATE Feb 21, 2009 DEPTH 2899' PRESENT OPERATION Repair top drive; assemble BHA TIME 04:OOam YESTERDAY 2800' 24 HOUR FOOTAGE 99' CASING 9.625" @ INFORMATION 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 2899' 0 @ 2899' 0.0 FT /HR SURFACE TORQUE 0 @ 2899' 0 @ 2899' 0.0 AMPS WEIGHT ON BIT 0 @ 2899' 0 @ 2899' 0.0 KLBS ROTARY RPM 0 @ 2899' 0 @ 2899' 0.0 RPM W MP PRESSURE 0 @ 2899' 0 @ 2899' 0.0 PSI ILLING MUD REPORT DEPTH MW 9.8 VIS 62 PV 13 YP 24 FL Gels 9/21/- CL- 20000 FC 2/- SOL 6.4 SD 0.30 OIL -/92 MBL 12.5 pH 9.8 Ca+ 400 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 2899' 0 @ 2899' 0.0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 0 @ 2899' 0 @ 2899' 0.0 CONNECTION GAS HIGH ETHANE (C -2) 0 @ 2899' 0 @ 2899' 0.0 AVG PROPANE (C -3) 0 @ 2899' 0 @ 2899' 0.0 CURRENT BUTANE (C -4) 0 @ 2899' 0 @ 2899' 0.0 CURRENT BACKGROUND /AVG PENTANE (C -5) 0 @ 2899' 0 @ 2899' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION • file: / //Cl/Documents and Settings/RigUser /My Documents /My Wells/Chevron_Alaska/20090221.htm (1 of 2)2/21/2009 4:22:48 AM Daily Report LITHOLOGY PRESENT HOLOGY ILY ACTIVITY SUMMARY EPOCH PERSONNEL ON DAILY 4 $4875.00 BOARD COST REPORT BY C. Medlyn /J. Vanderberg • file: / / /Cl/Documents and Settings/RigUser /My Documents /My Wells/Chevron_Alaska/20090221.htm (2 of 2)2/21/2009 4:22:48 AM Daily Report Chevron • Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR Don Fowler /Brad Rasch DATE Feb 22, DEPTH 2899' PRESENT OPERATION Changing Well Head/ BOP Test/Preparing Milling BHA 2009 TIME 04:00 YESTERDAY 2899' 24 HOUR FOOTAGE 0 CASING 9.625" 3000 INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 2899' 0 @ 2899' 0.0 FT /HR SURFACE TORQUE 0 @ 2899' 0 @ 2899' 0.0 AMPS WEIGHT ON BIT 0 @ 2899' 0 @ 2899' 0.0 KLBS � TARY RPM 0 @ 2899' 0 @ 2899' 0.0 RPM MP PRESSURE 0 @ 2899' 0 @ 2899' 0.0 PSI DRILLING MUD REPORT DEPTH MW 9.80 VIS 63 PV 11 YP 26 FL 7.6 Gels 7/12/- CL- 21000 FC 2/- SOL 6.8 SD .3 OIL .5/91.0 MBL 12.5 pH 9.8 Ca+ 400 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 2899' 0 @ 2899' 0.0 TRIP GAS CUTTING GAS 0 @ 2899' 0 @ 2899' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 0 @ 2899' 0 @ 2899' 0.0 CONNECTION GAS HIGH ETHANE (C -2) 0 @ 2899' 0 @ 2899' 0.0 AVG PROPANE (C -3) 0 @ 2899' 0 @ 2899' 0.0 CURRENT BUTANE (C -4) 0 @ 2899' 0 @ 2899' 0.0 CURRENT BACKGROUND /AVG PENTANE (C -5) 0 @ 2899' 0 @ 2899' 0.0 HYDROCARBON SHOWS •TERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file: / / /Cl/Documents and Settings/RigUser /My Documents /My Wells/Chevron_Alaska/20090222.htm (1 of 2)2/22/2009 4:15:52 AM Daily Report LITHOLOGY PRESENT HOLOGY ILY ACTIVITY SUMMARY EPOCH PERSONNEL ON 4 DAILY $5875.00 BOARD COST REPORT BY C. Medlyn /J. VanderBerg S S file: / / /Cl/Documents and Settings /RigUser/My Documents /My Wells/Chevron_Alaska/20090222.htm (2 of 2)2/22/2009 4:15:52 AM Daily Report Chevron • Stump Lake DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR Don Fowler /Brad Rasch DATE Feb 23, 2009 DEPTH 2899' PRESENT OPERATION Setting Whipstock TIME 01:00 YESTERDAY 2899' 24 HOUR FOOTAGE 0 CASING 9.625" 3000' INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 2899' 0 @ 2899' 0.0 FT /HR SURFACE TORQUE 0 @ 2899' 0 @ 2899' 0.0 AMPS WEIGHT ON BIT 0 @ 2899' 0 @ 2899' 0.0 KLBS ROTARY RPM 0 @ 2899' 0 @ 2899' 0.0 RPM IF MP PRESSURE 0 @ 2899' 0 @ 2899' 0.0 PSI ILLING MUD REPORT DEPTH 2899' MW 9.70 VIS 68 PV 13 YP 24 FL 8.0 Gels 8/18/- CL- 21000 FC 2/- SOL 7.8 SD .3 OIL .5/90.0 MBL 12.0 pH 9.6 Ca+ 400 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 2899' 0 @ 2899' 0.0 TRIP GAS CUTTING GAS 0 @ 2899' 0 @ 2899' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 0 @ 2899' 0 @ 2899' 0.0 CONNECTION GAS HIGH ETHANE (C -2) 0 @ 2899' 0 @ 2899' 0.0 AVG PROPANE (C -3) 0 @ 2899' 0 @ 2899' 0.0 CURRENT BUTANE (C -4) 0 @ 2899' 0 @ 2899' 0.0 CURRENT BACKGROUND /AVG PENTANE (C -5) 0 @ 2899' 0 @ 2899' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION 410 file:///q/Documents and Settings/RigUser /My Documents /My Wells/Chevron_Alaska/20090223.htm (1 of 2)2/23/2009 1:37:55 AM Daily Report ill LITHOLOGY PRESENT THOLOGY ILY ACTIVITY SUMMARY EPOCH PERSONNEL ON 4 DAILY 4875.00 BOARD COST REPORT BY C. Medlyn /J. VanderBerg • III file: / / /C1/Documents and Settings/RigUser /My Documents /My Wells/Chevron_Alaska/20090223.htm (2 of 2)2/23/2009 1:37:55 AM Daily Report Chevron Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR Don Fowler /Brad Rasch DATE Feb. 24, 2009 DEPTH 2880' PRESENT OPERATION M/U drilling BHA to RIH to drill 20 more feet. TIME 01:30am YESTERDAY 2868' 24 HOUR FOOTAGE 12' CASING 9.625" @ INFORMATION 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 8.5" HTC MXL -09DX 6054051 3x16 2880' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 2880' 0 @ 2880' 0.0 FT /HR SURFACE TORQUE 0 @ 2880' 0 @ 2880' 0.0 AMPS WEIGHT ON BIT 0 @ 2880' 0 @ 2880' 0.0 KLBS •TARY RPM 0 @ 2880' 0 @ 2880' 0.0 RPM MP PRESSURE 0 @ 2880' 0 @ 2880' 0.0 PSI DRILLING MUD REPORT DEPTH 2880' MW 10.0 VIS 59 PV 18 YP 21 FL 8.4 Gels 9/21/- CL- 29000 FC 1/- SOL 8.7 SD 0 OIL -/89 MBL 10 pH 9.10 Ca+ 240 CCI MWD SUMMARY INTERVAL 2880' TO 2880' TOOLS MWD + Mud Motor GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 2880' 0 @ 2880' 0.0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 0 @ 2880' 0 @ 2880' 0.0 CONNECTION GAS HIGH ETHANE (C -2) 0 @ 2880' 0 @ 2880' 0.0 AVG PROPANE (C -3) 0 @ 2880' 0 @ 2880' 0.0 CURRENT BUTANE (C -4) 0 @ 2880' 0 @ 2880' 0.0 CURRENT BACKGROUND /AVG PENTANE (C -5) 0 @ 2880' 0 @ 2880' 0.0 HYDROCARBON SHOWS TERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file: / / /Cl/Documents and Settings/RigUser/My Documents /My Wells/Chevron_Alaska/20090224.htm (1 of 2)2/24/2009 1:28:49 AM Daily Report LITHOLOGY PRESENT HOLOGY • ILY ACTIVITY M/U milling assembly; RIH; mill window and drill 12'; CBU; POOH; perform leak off test; M/U drilling SUMMARY BHA EPOCH PERSONNEL ON 4 DAILY $4875 BOARD COST REPORT BY C. Medlyn /J. Vanderberg 110 • file: / / /Cl/Documents and Settings/RigUser/My Documents /My Wells /Chevron_Alaska/20090224.htm (2 of 2)2/24/2009 1:28:49 AM Daily Report Chevron S Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR Don Fowler /Brad Rasch DATE Feb. 25, 2009 DEPTH 2880' PRESENT OPERATION Circ prior to running gyro TIME 01:30am YESTERDAY 2880' 24 HOUR FOOTAGE 0' CASING 9.625" @ INFORMATION 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 8.5" HTC MXL -09DX 6054051 3x16 2880' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS TARY RPM @ @ RPM ii PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2880' MW 9.3 VIS 58 PV 13 YP 23 FL 6.2 Gels 8/14/- CL- 29000 FC 1/- SOL 4.6 SD 0.10 OIL -/93 MBL 2.5 pH 8.0 Ca+ 400 CCI MWD SUMMARY INTERVAL 2880' TO 2880' TOOLS MWD + Mud Motor GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS �TERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file: / / /Cl/Documents and Settings/RigUser /My Documents /My Wells /Chevron_Alaska/20090225.htm (1 of 2)2/25/2009 1:26:16 AM I Report LITHOLOGY PRESENT HOLOGY ILY ACTIVITY Do repairs to top drive; M/U BHA; P/U DP to 2843'; do shallow hole test; POOH; M/U remaining SUMMARY DP EPOCH PERSONNEL ON 4 DAILY $4875 BOARD COST REPORT BY C. Medlyn /J. Vanderberg file: / / /Cl/Documents and Settings/RigUser /My Documents/My Wells /Chevron_Alaska/20090225.htm (2 of 2)2/25/2009 1:26:16 AM Daily Report Chevron • Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR Ron Fowler /Brad Rasch DATE Feb 26, 2009 DEPTH 3815' PRESENT OPERATION Drilling TIME 04:OOam YESTERDAY 2800' 24 HOUR FOOTAGE 1015' CASING 9.625" @ INFORMATION 3000' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3717.18' 29.54 315.87 3686.00 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 8.5" HTC MXL -09DX 6054051 3x16 2880' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 551.9 @ 3135' 23.5 @ 3662' 129.1 118.40 FT /HR SURFACE TORQUE 6467 @ 3327' 14 @ 3679' 1286.9 3287.17 AMPS WEIGHT ON BIT 16 @ 3571' 0 @ 3055' 4.3 7.17 KLBS TARY RPM 69 @ 3419' 0 @ 2914' 28.4 54.58 RPM PUMP PRESSURE 2516 @ 3685' 540 @ 3612' 1947.1 2320.74 PSI DRILLING MUD REPORT DEPTH 3601' MW 9.2 VIS 51 PV 11 YP 22 FL 5.0 Gels 7/12/18 CL- 22000 FC 1/- SOL 4.7 SD 0.12 OIL -/93.5 MBL 5.0 pH 9.0 Ca+ 400 CCI MWD SUMMARY INTERVAL 2880' TO 3815' TOOLS MWD + Mud Motor GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 3 @ 3709' 0 @ 3504' 1.1 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C -1) 0 @ 3815' 0 @ 3815' 0.0 CONNECTION GAS HIGH N/A ETHANE (C -2) 0 @ 3815' 0 @ 3815' 0.0 AVG N/A PROPANE (C -3) 0 @ 3815' 0 @ 3815' 0.0 CURRENT N/A BUTANE (C -4) 0 @ 3815' 0 @ 3815' 0.0 CURRENT BACKGROUND /AVG 17/20 PENTANE (C -5) 0 @ 3815' 0 @ 3815' 0.0 illtDROCARBON SHOWS No shows ERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file: / / /C[/Documents and Settings/RigUser /My Documents /My Wells/Chevron_Alaska/20090226.htm (1 of 2)2/26/2009 3:53:49 AM Daily Report LITHOLOGY Sterling PRESENT 40% Sand; 20% Coal; 40% Volcanics 1 111HOLOGY (ash) DAILY ACTIVITY Run wireline gyro; began drilling w/ occ stops for wireline SUMMARY gyro; EPOCH PERSONNEL ON 4 DAILY $4875.00 BOARD COST REPORT BY C. Medlyn /J. Vanderberg S file: / / /Cl/Documents and Settings/RigUser /My Documents /My Wells /Chevron_Alaska/20090226.htm (2 of 2)2/26/2009 3:53:49 AM Daily Report Chevron Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR D. Fowler /A. Purugganan DATE Feb 27, 2009 DEPTH 5360' PRESENT OPERATION Drilling TIME 03:OOam YESTERDAY 3816' 24 HOUR FOOTAGE 1544' CASING 9.625" @ INFORMATION 3000' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5146.6' 46.96 321.89 4682.96' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 8.5" HTC MXL -09DX 6054051 3x16 2880' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 491.9 @ 4007' 22.0 @ 4565' 146.9 189.76 FT /HR SURFACE TORQUE 7300 @ 5193' 14 @ 5359' 3257.7 0.00 AMPS WE IGHT ON BIT 19 @ 3990' 0 @ 3896' 6.9 5.83 KLBS • TARY RPM 65 @ 5031' 0 @ 3977' 45.9 0.82 RPM PUMP PRESSURE 2706 @ 5137' 1867 @ 4540' 2540.3 2680.96 PSI DRILLING MUD REPORT DEPTH 5164' MW 9.2 VIS 46 PV 12 YP 22 FL 4.6 Gels 6/10/14 CL- 31000 FC 1/- SOL 4.0 SD 0.50 OIL -/93.5 MBL 5.0 pH 9.1 Ca+ 520 CCI MWD SUMMARY INTERVAL 3816' TO 5360' TOOLS MWD + Mud motor GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 84 @ 4321' 0 @ 4902' 17.7 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C -1) 218802 @ 3869' 22 @ 4097' 13930.1 CONNECTION GAS HIGH N/A ETHANE (C -2) 0 @ 5360' 0 @ 5360' 0.0 AVG 0 u PROPANE (C -3) 0 @ 5360' 0 @ 5360' 0.0 CURRENT 0 u BUTANE (C -4) 0 @ 5360' 0 @ 5360' 0.0 CURRENT BACKGROUND /AVG 11 u PENTANE (C -5) 0 @ 5360' 0 @ 5360' 0.0 DROCARBON SHOWS No shows. IOW ERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file: / / /G/DOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS /MY WELLS /CHEVRON_ALASKA/20090227.htm (1 of 2)2/27/2009 2:58:15 AM Daily Report LITHOLOGY Sterling PRESENT 80% Sand /Conglomeritic sand; 20% Tuffaceous THOLOGY Claystone AILY ACTIVITY Drilled to 4563' then made wiper trip to shoe; RTB; resume SUMMARY drilling. EPOCH PERSONNEL ON 4 DAILY $4875.00 BOARD COST REPORT BY C. Medlyn /J. Vanderberg • S file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS /MY WELLS /CHEVRON_ALASKA/20090227.htm (2 of 2)2/27/2009 2:58:15 AM Daily Report Chevron USA • Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR D. Fowler /A. Purugganan DATE Feb 28, 2009 DEPTH 6123' PRESENT OPERATION L/D MWD tools and 8.5" bit TIME 03:OOam YESTERDAY 5361' 24 HOUR FOOTAGE 762' CASING 9.625" @ INFORMATION 3000' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6038' 18.10 315.95 5428.83' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 8.5" HTC MXL -09DX 6054051 3x16 2900' 6123' 3223' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 409.6 @ 6096' 15.7 @ 6088' 141.4 90.61 FT /HR SURFACE TORQUE 6868 @ 5680' 14 @ 6009' 3118.0 5077.76 AMPS WEIGHT ON BIT 21 @ 6102' 0 @ 5708' 6.2 6.22 KLBS •TARY RPM 67 @ 6035' 0 @ 5848' 36.9 59.87 RPM PUMP PRESSURE 2881 @ 5978' 2583 @ 6088' 2734.5 2624.35 PSI DRILLING MUD REPORT DEPTH 6123' MW 9.4 VIS 45 PV 13 YP 22 FL 5.8 Gels 6/8/14 CL- 31000 FC 1/- SOL 5.5 SD 0.5 OIL -/92 MBL 6.2 pH 8.5 Ca+ 520 CCI MWD SUMMARY INTERVAL 5361' TO 6123' TOOLS MWD + Mud Motor GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 121 @ 6026' 1 @ 5387' 24.0 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS 54.5 u CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C -1) 19917 @ 5578' 254 @ 5387' 3818.9 CONNECTION GAS HIGH N/A ETHANE (C -2) 0 @ 6123' 0 @ 6123' 0.0 AVG N/A PROPANE (C -3) 0 @ 6123' 0 @ 6123' 0.0 CURRENT N/A BUTANE (C -4) 0 @ 6123' 0 @ 6123' 0.0 CURRENT BACKGROUND /AVG N/A PENTANE (C -5) 0 @ 6123' 0 @ 6123' 0.0 W DROCARBON SHOWS Good gas shows in the Beluga coals. ERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file: / / /CVDOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS /MY WELLS /CHEVRON_ALASKA/20090227.htm (1 of 2)2/28/2009 2:59:37 AM Daily Report LITHOLOGY Lower Sterling PRESENT 80% Tuffaceous Claystone; 10% Sandstone; 10% THOLOGY Sand _ ILY ACTIVITY Drilled to casing point; wipe hole; RTB; CBU and carbide; POOH; L/D DP & SUMMARY BHA. EPOCH PERSONNEL ON 4 DAILY $4875.00 BOARD COST REPORT BY C. Medlyn /J. Vanderberg • 0 file: / / /Cl/DOCUMENTS AND SETTINGS/RIGUSER/M...UMENTS /MY WELLS /CHEVRON_ALASKA/20090227.htm (2 of 2)2/28/2009 2:59:37 AM Daily Report Chevron USA S tump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR D. Fowler /A. Purugganan DATE Mar 1, 2009 DEPTH 6123' PRESENT OPERATION Cementing 7" Casing TIME 03:OOam YESTERDAY 6123' 24 HOUR FOOTAGE 0' CASING 9.625" @ 7" INFORMATION 3000' @ ?? SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM MP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH Mud Report Unavailable MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 47u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION • file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS/MY WELLS /CHEVRON_ALASKA/20090227.htm (1 of 2)3/1/2009 2:43:03 AM Daily Report LITHOLOGY PRESENT T HOLOGY ILY ACTIVITY POOH; LID BHA; Change BOP Rams; Run casing; SUMMARY Circulate EPOCH PERSONNEL ON 4 DAILY $4875.00 BOARD COST REPORT BY C. Medlyn /J. Vanderberg • file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS /MY WELLS/CHEVRON_ALASKA/20090227.htm (2 of 2)3/1/2009 2:43:03 AM Daily Report Chevron USA IP Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR D. Fowler/ A. Purugganan DATE Mar 02, 2009 DEPTH 6123' PRESENT OPERATION BOP TIME 14:07:21 YESTERDAY 6123' 24 HOUR FOOTAGE 0 CASING 9.625" @ 7" @ INFORMATION 3000" 6123" SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM MP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.5 VIS 48 PV 11 YP 24 FL 5.3 Gels 6/8/14 CL- 28000 FC 1/- SOL 6.6 SD .5 OIL -/91.2 MBL 6.0 pH 8.8 Ca+ 520 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS o TERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS /MY WELLS /CHEVRON_ALASKA/20090227.htm (1 of 2)3/2/2009 2:05:51 AM Daily Report LITHOLOGY PRESENT HOLOGY AILY ACTIVITY Cementing Casing/ Setting SUMMARY BOP EPOCH PERSONNEL ON DAILY 4875 BOARD 4 COST $ REPORT BY J. VanderBerg/ C. Medlyn 41111 file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS /MY WELLS /CHEVRON_ALASKA/20090227.htm (2 of 2)3/2/2009 2:05:51 AM Daily Report ill10 Chevron USA S tump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR D. Fowler/ A. Purugganan DATE Mar 03, 2009 DEPTH 6123' PRESENT OPERATION Building BHA TIME 14:07:21 YESTERDAY 6123' 24 HOUR FOOTAGE 0 CASING 9.625" 7" @ INFORMATION @3000' 6123' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM MP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 6123' MW 9.45 VIS 49 PV 8 YP 20 FL 5.6 Gels 6/8/12 CL- 27000 FC 1/- SOL 6.3 SD .5 OIL -/91.5 MBL 6.2 pH 8.5 Ca+ 680 CCI BOP MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS TERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file: / / /CVDOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS /MY WELLS /CHEVRON_ALASKA/20090227.htm (1 of 2)3/3/2009 2:26:51 AM Daily Report LITHOLOGY PRESENT THOLOGY ILY ACTIVITY BOP Test/ Assemble SUMMARY BHA EPOCH PERSONNEL ON DAILY 4875 BOARD 4 COST $ REPORT BY C. Medlyn/ J. VanderBerg • • file:///G/DOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS /MY WELLS /CHEVRON_ALASKA/20090227.htm (2 of 2)3/3/2009 2:26:51 AM Daily Report 4 6 Chevron USA S tump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR M. Leslie /A. Purugganan DATE Mar 04, 2009 DEPTH 6432' PRESENT OPERATION Drilling TIME 05:30am YESTERDAY 6123' 24 HOUR FOOTAGE 309' CASING 9.625" @ 7" @ INFORMATION 3000' 6120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 6 -1/8" MSX513M -A1B 124943 3x9,2x10 6123' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 272.6 @ 6388' 18.9 @ 6176' 152.1 117.84 FT /HR SURFACE TORQUE 8134 @ 6177' 4336 @ 6252' 5768.4 4630.11 AMPS WEIGHT ON BIT 6 @ 6128' 0 @ 6413' 3.4 1.18 KLBS OTARY RPM 122 @ 6430' 0 @ 6143' 104.7 118.04 RPM MP PRESSURE 2624 @ 6123' 1842 @ 6148' 2193.6 2300.16 PSI DRILLING MUD REPORT DEPTH 6123' MW 9.4 VIS 50 PV 7 YP 17 FL 5.6 Gels 5/8/11 CL- 26500 FC 1/- SOL 5.9 SD 0.50 OIL -/92 MBL 6.2 pH 8.35 Ca+ 600 CCI MWD SUMMARY INTERVAL 6123' TO 6432' TOOLS MWD + Mud motor + ADN (nuclear) GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 345 @ 6342' 1 @ 6259' 27.4 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C -1) 227101 @ 6342' 115 @ 6181' 11207.5 CONNECTION GAS HIGH N/A ETHANE (C -2) 0 @ 6432' 0 @ 6432' 0.0 AVG N/A PROPANE (C -3) 0 @ 6432' 0 @ 6432' 0.0 CURRENT NA BUTANE (C -4) 0 @ 6432' 0 @ 6432' 0.0 CURRENT BACKGROUND /AVG 45u PENTANE (C -5) 0 @ 6432' 0 @ 6432' 0.0 HYDROCARBON SHOWS ERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS/MY WELLS /CHEVRON_ALASKA/20090304.htm (1 of 2)3/4/2009 5:44:40 AM Daily Report LITHOLOGY PRESENT Tuffaceous claystone; Tuffaceous T HOLOGY siltstones AILY ACTIVITY SUMMARY EPOCH PERSONNEL ON 4 DAILY $4875 BOARD COST REPORT BY C. Medlyn /J. Vanderberg • • file: / / /CVDOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS /MY WELLS /CHEVRON_ALASKA/20090304.htm (2 of 2)3/4/2009 5:44:40 AM Daily Report Chevron USA Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR M. Leslie /A. Purugganan DATE 3 -5 -2009 DEPTH 7170' PRESENT OPERATION Drilling TIME 03:30am YESTERDAY 6433' 24 HOUR FOOTAGE 737' CASING 9.625" @ 7" @ INFORMATION 3000' 6120' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7085' 0.10 2.08 6462.76' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 6 -1/8" MSX513M -A1B 124943 3x9,2x10 6123' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 253.1 @ 6591' 7.2 @ 7148' 66.9 54.29400 FT /HR SURFACE TORQUE 10032 @ 6849' 3688 @ 6550' 4320.6 AMPS WEIGHT ON BIT 14 @ 6628' 0 @ 6565' 7.0 10.47500 KLBS ARY RPM 120 @ 6780' 104 @ 6617' 78.5 RPM PUMP PRESSURE 2773 @ 6668' 1919 @ 6458' 1742.2 PSI DRILLING MUD REPORT DEPTH 7122' MW 10.0 VIS 46 PV 9 YP 22 FL 5.4 Gels 5/8/15 CL- 30000 FC 1/- SOL 7.6 SD 0.25 OIL -/90 MBL 6.5 pH 9.1 Ca+ 680 CCI MWD SUMMARY INTERVAL 6433' TO 7170' TOOLS MWD + Mud Motor + ADN (nuclear) GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 79 @ 7166' 1 @ 7037' 13.6 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C -1) 54448 @ 7166' 159 @ 7037' 7114.8 CONNECTION GAS HIGH 7.5u ETHANE (C -2) 0 @ 7170' 0 @ 7170' 0.0 AVG 3.2u PROPANE (C -3) 0 @ 7170' 0 @ 7170' 0.0 CURRENT N/A BUTANE (C -4) 0 @ 7170' 0 @ 7170' 0.0 CURRENT BACKGROUND /AVG 26.4/10u PENTANE (C -5) 0 @ 7170' 0 @ 7170' 0.0 DROCARBON SHOWS ERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS /MY WELLS /CHEVRON_ALASKA/20090305.htm (1 of 2)3/5/2009 3:03:59 AM Daily Report LITHOLOGY PRESENT 60% Coal; 20% Tuffaceous Claystone; 10% Sand; 10% Conglomeritic THOLOGY ILY ACTIVITY Sandstone Drilled SUMMARY ahead EPOCH PERSONNEL ON 4 DAILY $4875 BOARD COST REPORT BY C. Medlyn /J. Vanderberg III 0 file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS /MY WELLS/CHEVRON_ALASKA/20090305.htm (2 of 2)3/5/2009 3:03:59 AM Daily Report Chevron USA • Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR M. Leslie /A. Purugganan DATE Mar 06, 2009 DEPTH 7880' PRESENT OPERATION Drilling TIME 3:30am YESTERDAY 7171' 24 HOUR FOOTAGE 709' CASING 9.625" @ 7" @ INFORMATION 3000' 6120' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7850' 0.12 277.32 7227.20' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 6 -1/8" MSX513M -A1B 124943 3x9,2x10 6120' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 825.9 @ 7339' 4.8 @ 7244' 48.1 33.50 FT /HR SURFACE TORQUE 9631 @ 7208' 4136 @ 7738' 6829.6 7609.29 AMPS EIGHT ON BIT 29 @ 7201' 3 @ 7244' 12.8 13.74 KLBS TARY RPM 152 @ 7498' 88 @ 7441' 96.2 121.38 RPM PUMP PRESSURE 3046 @ 7711' 2341 @ 7309' 2723.4 2963.99 PSI DRILLING MUD REPORT DEPTH 7804' MW 10.1 VIS 49 PV 16 YP 22 FL 4.0 Gels 5/10/16 CL- 30000 FC 1/- SOL 8.7 SD 0.25 OIL 1.0/88 MBL 6.2 pH 9.2 Ca+ 220 CCI MWD SUMMARY INTERVAL 7171' TO 7880' TOOLS MWD + Mud Motor + ADN (nuclear) GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 583 @ 7635' 0 @ 7438' 27.5 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C -1) 606664 @ 7443' 98 @ 7438' 16996.4 CONNECTION GAS HIGH 63u ETHANE (C -2) 0 @ 7880' 0 @ 7880' 0.0 AVG 30u PROPANE (C -3) 0 @ 7880' 0 @ 7880' 0.0 CURRENT 46u BUTANE (C -4) 0 @ 7880' 0 @ 7880' 0.0 CURRENT BACKGROUND /AVG 70u /30u PENTANE (C -5) 0 @ 7880' 0 @ 7880' 0.0 W DROCARBON SHOWS Intermittent high gas peaks from coal /carbonaceous shale zones. ERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file:///C/DOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS /MY WELLS /CHEVRON_ALASKA/20090306.htm (1 of 2)3/6/2009 3:35:30 AM Daily Report LITHOLOGY Sterling/Tyonek PRESENT 40% tuffaceous claystone; 20% tuffaceous siltstone; 10% coal; 10% carbonaceous shale; 10% sand; 10% HOLOGY tuffaceous shale ILY ACTIVITY Drilled SUMMARY ahead EPOCH PERSONNEL ON 4 DAILY $4875 BOARD COST REPORT BY C. Medlyn /J. Vanderberg • file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS/MY WELLS /CHEVRON_ALASKA/20090306.htm (2 of 2)3/6/2009 3:35:30 AM Daily Report Chevron USA Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR M. Leslie /A. Purugganan DATE March 7, 2009 DEPTH 8359' PRESENT OPERATION RIH after wiper trip to shoe. TIME 02:30am YESTERDAY 7881' 24 HOUR FOOTAGE 478' CASING 9.625" @ 7" @ INFORMATION 3000' 6120' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8323.29' 0.08 8.04 7700.19' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 6-1/8" MSX513M -A1 B 124943 3x9,2x10 6120' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 119.0 @ 7968' 6.5 @ 7951' 49.8 26.46' FT /HR SURFACE TORQUE 9106 @ 7938' 5741 @ 8007' 7512.4 AMPS WEIGHT ON BIT 18 @ 8023' 0 @ 8049' 15.1 10.28' KLBS •TARY RPM 131 @ 8267' 111 @ 8253' 117.8 RPM PUMP PRESSURE 3133 @ 8230' 2680 @ 8135' 2998.0 PSI DRILLING MUD REPORT DEPTH 8359' MW 10.4 VIS 49 PV 15 YP 25 FL 4.2 Gels 6/19/24 CL- 30000 FC 1/- SOL 9.2 SD 0.25 OIL 1.5/87 MBL 7.5 pH 8.4 Ca+ 240 CCI MWD SUMMARY INTERVAL 7881' TO 8359' TOOLS MWD + Mud Motor + ADN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 132 @ 7951' 0 @ 8161' 25.9 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C -1) 97691 @ 8193' 15 @ 8161' 16910.2 CONNECTION GAS HIGH 116u ETHANE (C -2) 0 @ 8359' 0 @ 8359' 0.0 AVG 12u PROPANE (C -3) 0 @ 8359' 0 @ 8359' 0.0 CURRENT N/A BUTANE (C -4) 0 @ 8359' 0 @ 8359' 0.0 CURRENT BACKGROUND /AVG N/A PENTANE (C -5) 0 @ 8359' 0 @ 8359' 0.0 W DROCARBON SHOWS Various gas peaks associated with small coal beds. ERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS /MY WELLS/CHEVRON_ALASKA/20090307.htm (1 of 2)3/7/2009 2:31:06 AM Daily Report LITHOLOGY Just above the Tyonek. PRESENT 40% Tuffaceous Claystone; 10% each of Tuffaceous shale, carbonaceous shale, tuffaceous siltstone, coal, HOLOGY sand and conglomeritic sand. ILY ACTIVITY Drilled to 8359'; CBU; make wiper trip to shoe, SUMMARY RTB. EPOCH PERSONNEL ON 4 DAILY $4875.00 BOARD COST REPORT BY C. Medlyn /J. Vanderberg • file: / / /C]/DOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS /MY WELLS/CHEVRON_ALASKA/20090307.htm (2 of 2)3/7/2009 2:31:06 AM Daily Report Chevron USA II Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR M. Leslie /A. Purugganan DATE Mar 08, 2009 DEPTH 8712' PRESENT OPERATION POOH for bit change. TIME 03:30am YESTERDAY 8360' 24 HOUR FOOTAGE 352' CASING 9.625" @ 7" @ INFORMATION 3000' 6120' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8611.58' 0.05 69.47 7988.48' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 6 -1/8" MSX513M -A1B 124943 3x9,2x10 6120' 8721' 2601' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 115.6 @ 8510' 7.0 @ 8578' 36.2 13.53 FT /HR SURFACE TORQUE 10063 @ 8533' 4784 @ 8655' 7203.8 6837.49 AMPS WEIGHT ON BIT 23 @ 8636' 1 @ 8360' 13.3 20.38 KLBS •TARY RPM 131 @ 8644' 82 @ 8633' 122.0 110.92 RPM PUMP PRESSURE 3385 @ 8633' 2711 @ 8438' 3082.7 3210.99 PSI DRILLING MUD REPORT DEPTH 8721' MW 10.9 VIS 49 PV 14 YP 25 FL 4.6 Gels 6/15/19 CL- 29000 FC 1/- SOL 12.4 SD 0.25 OIL 1.0/84.5 MBL 7.5 pH 9.0 Ca+ -- CCI MWD SUMMARY INTERVAL 8360' TO 8712' TOOLS MWD + Mud Motor + ADN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 100 @ 8553' 0 @ 8430' 24.3 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS 781u CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C -1) 136957 @ 8395' 633 @ 8375' 20897.7 CONNECTION GAS HIGH 24u ETHANE (C -2) 0 @ 8712' 0 @ 8712' 0.0 AVG 4u PROPANE (C -3) 0 @ 8712' 0 @ 8712' 0.0 CURRENT N/A BUTANE (C -4) 0 @ 8712' 0 @ 8712' 0.0 CURRENT BACKGROUND /AVG N/A PENTANE (C -5) 0 @ 8712' 0 @ 8712' 0.0 AlliDROCARBON SHOWS Intermittent gas peaks associated with coal and sand stringers. "ERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS /MY WELLS /CHEVRON_ALASKA/20090308.htm (1 of 2)3/8/2009 3:26:44 AM Daily Report LITHOLOGY Tyonek PRESENT 60% Tuffaceous Claystone; 10% Tuffaceous Siltstone; 10% Carbonaceous Shale; 10% Coal; 10% HOLOGY Sand ILY ACTIVITY RIH after wiper trip; circ. out gas; resume drilling; POOH for bit SUMMARY change. EPOCH PERSONNEL ON DAILY 4 $4875.00 BOARD COST REPORT BY C. Medlyn /J. Vanderberg • • file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS /MY WELLS /CHEVRON_ALASKAJ20090308.htm (2 of 2)3/8/2009 3:26:44 AM Daily Report Chevron USA S tump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR M. Leslie /A. Purugganan DATE Mar 09, 2009 DEPTH 8735' PRESENT OPERATION Drilling TIME 02:OOam YESTERDAY 8713' 24 HOUR FOOTAGE 22' CASING 9.625" @ 7" @ INFORMATION 3000' 6120' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA no new surveys BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 6 -1/8" HCM505ZX 7010032 4x10,1x12 8721' 2 6 -1/8" MSX513M -A1B 124943 3x9,2x10 6120' 8721' 2601' 25.8 3- 2- LT- A- E- 3 -NO -TD Slow drilling DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 62.5 @ 8729' 4.9 @ 8722' 17.5 5.78 FT /HR SURFACE TORQUE 8334 @ 8728' 6081 @ 8720' 6788.4 8026.07 AMPS IGHT ON BIT 20 @ 8715' 2 @ 8727' 13.2 7.80 KLBS ROTARY RPM 116 @ 8715' 101 @ 8735' 104.6 101.82 RPM PUMP PRESSURE 3288 @ 8729' 3138 @ 8722' 3085.4 3210.99 PSI DRILLING MUD REPORT DEPTH 8721' MW 10.85 VIS 51 PV 16 YP 19 FL 4.6 Gels 5/14/19 CL- 29500 FC 1/- SOL 12.3 SD 0.25 OIL 1.0/84.5 MBL 7.5 pH 9.5 Ca+ 260 CCI MWD SUMMARY INTERVAL 8721' TO 8735' TOOLS MWD + Mud motor + ADN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 113 @ 8723' 5 @ 8735' 26.5 TRIP GAS 240u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C -1) 72933 @ 8723' 5624 @ 8731' 16439.5 CONNECTION GAS HIGH N/A ETHANE (C -2) 0 @ 8735' 0 @ 8735' 0.0 AVG N/A PROPANE (C -3) 0 @ 8735' 0 @ 8735' 0.0 CURRENT N/A BUTANE (C -4) 0 @ 8735' 0 @ 8735' 0.0 CURRENT BACKGROUND /AVG 5.4u/10u Ei NTANE (C -5) 0 @ 8735' 0 @ 8735' 0.0 file:///Cl/DOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS /MY WELLS /CHEVRON_ALASKA/20090309.htm (1 of 2)3/9/2009 1:59:56 AM Daily Report HYDROCARBON SHOWS No shows INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION OLOGY Tyonek PRESENT 50% Tuffaceous claystone; 40% Sand; 10% Carbonaceous shales/ LITHOLOGY coal DAILY ACTIVITY POOH to change bit; L/D bent motor; P/U straight motor; RIH; resume SUMMARY drilling EPOCH PERSONNEL ON 4 DAILY $4875.00 BOARD COST REPORT BY C. Medlyn /J. Vanderberg 410 file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/MY...CUMENTS /MY WELLS /CHEVRON_ALASKA/20090309.htm (2 of 2)3/9/2009 1:59:56 AM Daily Report Chevron USA Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR M. Leslie /B. Rasch DATE Mar 10, 2009 DEPTH 9190' PRESENT OPERATION Drilling TIME 02:OOam YESTERDAY 8736' 24 HOUR FOOTAGE 454' CASING 9.625" @ 7" @ INFORMATION 3000' 6120' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9088' 0.73 141.21 8465.00 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 6 -1/8" HCM505ZX 7010032 4x10,1x12 8721' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 191.9 @ 9080' 5.7 @ 8736' 37.8 15.22 FT /HR SURFACE TORQUE 10326 @ 9180' 7084 @ 8772' 8453.6 8797.88 AMPS EIGHT ON BIT 16 @ 9127' 0 @ 9082' 10.7 7.37 KLBS ARY RPM 116 @ 8742' 76 @ 8751' 93.1 92.12 RPM PUMP PRESSURE 3787 @ 9180' 3036 @ 8761' 3452.7 3591.80 PSI DRILLING MUD REPORT DEPTH 8922' MW 10.9 VIS 53 PV 19 YP 24 FL 4.8 Gels 7/16/22 CL- 27000 FC 1/- SOL 13.0 SD 0.25 OIL 0.5/84.5 MBL 7.5 pH 9.0 Ca+ 240 CCI MWD SUMMARY INTERVAL 8736' TO 9190' TOOLS MWD + Mud Motor + ADN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 254 @ 9079' 2 @ 8749' 21.8 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C -1) 169482 @ 9079' 1105 @ 8870' 7814.2 CONNECTION GAS HIGH 73u ETHANE (C -2) 125 @ 8887' 2 @ 8901' 1.6 AVG 10u PROPANE (C -3) 0 @ 9190' 0 @ 9190' 0.0 CURRENT 7u BUTANE (C -4) 0 @ 9190' 0 @ 9190' 0.0 CURRENT BACKGROUND /AVG 7.5u/11u PENTANE (C -5) 0 @ 9190' 0 @ 9190' 0.0 DROCARBON SHOWS Various gas peaks at coals and sands. ERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS/MY WELLS /CHEVRON_ALASKA/20090310.htm (1 of 2)3/10/2009 2:30:46 AM Daily Report LITHOLOGY Tyonek PRESENT 60% Tuffaceous claystone; 20% Sand; 10% Tuffaceous siltstone; 10% Conglomeritic HOLOGY sandstone ILY ACTIVITY Drilled SUMMARY ahead EPOCH PERSONNEL ON 4 DAILY $4875.00 BOARD COST REPORT BY C. Medlyn /J. Vanderberg • 411 file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS /MY WELLS /CHEVRON_ALASKA/20090310.htm (2 of 2)3/10/2009 2:30:46 AM Daily Report , Chevron USA • Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR M. Leslie /B. Rasch DATE Mar 11, 2009 DEPTH 9520' PRESENT OPERATION Drilling TIME 03:30am YESTERDAY 9191' 24 HOUR FOOTAGE 329' CASING 9.625" @ 7" @ INFORMATION 3000' 6120' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9468.94' 0.51 198.62 8845.80' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 6 -1/8" HCM505ZX 7010032 4x10,1x12 8721' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 133.6 @ 9370' 5.6 @ 9276' 23.0 19.89 FT /HR SURFACE TORQUE 10295 @ 9363' 6636 @ 9492' 8447.8 9569.69 AMPS EIGHT ON BIT 20 @ 9495' 0 @ 9361' 12.5 8.59 KLBS TARY RPM 127 @ 9262' 45 @ 9260' 93.3 93.90 RPM PUMP PRESSURE 3854 @ 9495' 3478 @ 9255' 3629.7 3720.45 PSI DRILLING MUD REPORT DEPTH 9412' MW 11.1 VIS 46 PV 16 YP 18 FL 4.3 Gels 5/12/21 CL- 29000 FC 1/- SOL 13.4 SD 0.25 OIL 1.0/83.5 MBL 7.5 pH 9.3 Ca+ 200 CCI MWD SUMMARY INTERVAL 9191' TO 9520' TOOLS MWD + Mud Motor + ADN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 164 @ 9386' 4 @ 9222' 20.1 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C -1) 98149 @ 9434' 494 @ 9411' 8032.6 CONNECTION GAS HIGH 1027u ETHANE (C -2) 0 @ 9520' 0 @ 9520' 0.0 AVG 400u PROPANE (C -3) 0 @ 9520' 0 @ 9520' 0.0 CURRENT 427u BUTANE (C -4) 0 @ 9520' 0 @ 9520' 0.0 CURRENT BACKGROUND /AVG 13.8/12u PENTANE (C -5) 0 @ 9520' 0 @ 9520' 0.0 fill DROCARBON SHOWS Multiple gas shows with coals and sands. ERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file:/ / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS/MY WELLS /CHEVRON_ALASKA/20090311.htm (1 of 2)3/11/2009 3:36:48 AM Daily Report LITHOLOGY Tyonek PRESENT 30% Tuffaceous Claystone; 20% Sand; 10% Sandstone; 20% Tuffaceous Siltstone; 20% Carbonaceous THOLOGY Shale ILY ACTIVITY Drilled SUMMARY Ahead EPOCH PERSONNEL ON 4 DAILY $4875.00 BOARD COST REPORT BY C. Medlyn /J. Vanderberg • • file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS /MY WELLS/CHEVRON_ALASKA/20090311.htm (2 of 2)3/11/2009 3:36:48 AM Daily Report Chevron USA Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR M. Leslie /B. Rasch DATE Mar 12, 2009 DEPTH 10160' PRESENT OPERATION CBU prior to post -TD short trip TIME 02:30am YESTERDAY 9521' 24 HOUR FOOTAGE 639' CASING 9.625" @ 7" @ INFORMATION 3000' 6120' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA No data yet. BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 6 -1/8" HCM505ZX 7010032 4x10 8721' 10160' 7661' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 176.4 @ 9718' 6.9 @ 10160' 49.5 6.93 FT /HR SURFACE TORQUE 12054 @ 9831' 7393 @ 9696' 10163.1 9847.54 AMPS EIGHT ON BIT 16 @ 9849' 0 @ 10001' 8.8 10.15 KLBS TARY RPM 105 @ 9784' 86 @ 10003' 95.2 94.61 RPM PUMP PRESSURE 3869 @ 10147' 3267 @ 9620' 3626.5 3638.11 PSI DRILLING MUD REPORT DEPTH 10045' MW 11.4 VIS 48 PV 17 YP 18 FL 4.5 Gels 5/12/16 CL- 25000 FC 1/- SOL 13.2 SD 0.20 OIL 1.0/84 MBL 7.0 pH 8.6 Ca+ 260 CCI MWD SUMMARY INTERVAL 9521' TO 10160' TOOLS MWD + Mud Motor + ADN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 437 @ 10008' 10 @ 9595' 42.6 TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C -1) 302240 @ 10008' 2355 @ 9883' 19050.1 CONNECTION GAS HIGH 980u ETHANE (C -2) 14880 @ 10096' 2 @ 9764' 405.5 AVG 300u PROPANE (C -3) 1096 @ 10006' 1 @ 9741' 8.4 CURRENT N/A BUTANE (C -4) 0 @ 10160' 0 @ 10160' 0.0 CURRENT BACKGROUND /AVG N/A PENTANE (C -5) 0 @ 10160' -2 @ 9705' -0.0 • ROCARBON SHOWS Multiple gas shows ERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file: / / /Cl/DOCUMENTS AND SETTINGS/RIGUSER/M...UMENTS /MY WELLS /CHEVRON_ALASKA/20090312.htm (1 of 2)3/12/2009 2:38:24 AM Daily Report LITHOLOGY Tyonek PRESENT 90% Coal; 10% Carbonaceous Shale (in bottoms -up HOLOGY sample) ILY ACTIVITY Drilled ahead to TD of 10160'; CBU; pump sweep; condition hole for SUMMARY wireline EPOCH PERSONNEL ON 4 DAILY $4875.00 BOARD COST REPORT BY C. Medlyn /J. Vanderberg • • file: / / /Cl/DOCUMENTS AND SETTINGS/RIGUSER /M...UMENTS/MY WELLS /CHEVRON_ALASKA/20090312.htm (2 of 2)3/12/2009 2:38:24 AM Daily Report Chevron USA • Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR S. Lawrence /B. Rasch DATE Mar 12, 2009 DEPTH 10160' PRESENT OPERATION Circulating to condition hole for POOH TIME 03:30am YESTERDAY 10160' 24 HOUR FOOTAGE 0' CASING 9.625" @ 7" @ INFORMATION 3000' 6120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 6 -1/8" HCM 505ZX 7010032 4x10,1x12 8721' 10160' 1439' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS OTARY RPM @ @ RPM WMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10160' MW 11.6 VIS 49 PV 18 YP 20 FL 4.5 Gels 6/16/19 CL- 25000 FC 1/- SOL 13.7 SD 0.20 OIL 1.0/83.5 MBL 7.5 pH 9.0 Ca+ 260 CCI MWD SUMMARY INTERVAL 10160' TO 10160' TOOLS MWD + Mud Motor + ADN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS 1000+ u CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C -1) @ @ CONNECTION GAS HIGH N/A ETHANE (C -2) @ @ AVG N/A PROPANE (C -3) @ @ CURRENT 8.6u BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG < 15u PENTANE (C -5) @ @ HYDROCARBON SHOWS •TERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file: / / /CVDOCUMENTS AND SETTINGS/RIGUSER/M...UMENTS /MY WELLS/CHEVRON_ALASKA/20090312.htm (1 of 2)3/13/2009 3:32:12 AM Daily Report liot LITHOLOGY PRESENT THOLOGY ILY ACTIVITY SUMMARY EPOCH PERSONNEL ON 2 DAILY $4075.00 BOARD COST C. REPORT BY Medlyn • • file: / / /Cl/DOCUMENTS AND SETTINGS/RIGUSER/M...UMENTS /MY WELLS /CHEVRON_ALASKA/20090312.htm (2 of 2)3/13/2009 3:32:12 AM Daily Report Chevron USA II Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR S. Lawrence /B. Rasch DATE Mar 14, 2009 DEPTH 10160' PRESENT OPERATION Running wireline TIME 02:OOam YESTERDAY 10160' 24 HOUR FOOTAGE 0' CASING 9.625" @ 7" @ INFORMATION 3000' 6120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM W MP PRESSURE @ @ PSI ILLING MUD REPORT DEPTH 10160' MW 11.6 VIS 54 PV 18 YP 18 FL 4.8 Gels 6/14/18 CL- 24000 FC 1/- SOL 13.8 SD 0.20 OIL 1.0/83.4 MBL 7.5 pH 9.2 Ca+ 260 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION 0 file: / / /CVDOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS /MY WELLS/CHEVRON_ALASKA/20090312.htm (1 of 2)3/14/2009 1:47:43 AM Daily Report LITHOLOGY PRESENT HOLOGY ILY ACTIVITY Circulated 11.6 mud through system; back reamed out of hole; POOH; L/D BHA; prepare SUMMARY wireline EPOCH PERSONNEL ON 2 DAILY $4075.00 BOARD COST C. REPORT BY Medlyn • • file: / / /Cl/DOCUMENTS AND SETTINGS/RIGUSER /M...UMENTS/MY WELLS /CHEVRON_ALASKA/20090312.htm (2 of 2)3/14/2009 1:47:43 AM Daily Report Chevron USA III Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR S. Lawrence /B. Rasch DATE Mar 15, 2009 DEPTH 10160' PRESENT OPERATION Circulating 11.9 mud TIME 01:30am YESTERDAY 10160' 24 HOUR FOOTAGE 0 CASING 9.625" @ 7" @ INFORMATION 3000' 6120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM AMP PRESSURE @ @ PSI ILLING MUD REPORT DEPTH 10160' MW 11.8 VIS 56 PV 20 YP 18 FL 4.8 Gels 7/18/- CL- 24000 FC 2/- SOL 14.8 SD 0.50 OIL 0.5/83.0 MBL 10.0 pH 8.6 Ca+ 240 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 564u CUTTING GAS @ @ WIPER GAS 725u CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION • file: / / /C[/DOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS /MY WELLS /CHEVRON_ALASKA/20090312.htm (1 of 2)3/15/2009 1:29:13 AM Daily Report LITHOLOGY PRESENT HOLOGY ILY ACTIVITY Attempted wireline a -logs; could not get to bottom; RIH to make clean -out run; circ; raise MW to 11.9; SUMMARY circ; pump sweep; circ; EPOCH PERSONNEL ON 2 DAILY $4075.00 BOARD COST C. REPORT BY Medlyn S file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS /MY WELLS /CHEVRON_ALASKA/20090312.htm (2 of 2)3/15/2009 1:29:13 AM Daily Report Chevron USA • Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR S. Lawrence /B. Rasch DATE Mar 16, 2009 DEPTH 10160' PRESENT OPERATION Running wireline TIME 02:00am YESTERDAY 10160' 24 HOUR FOOTAGE 0' CASING 9.625" @ 7" @ INFORMATION 3000' 6120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PSI � MPPRESSURE LLING MUD REPORT DEPTH 10160' MW 11.9 VIS 64 PV 22 YP 23 FL 4.8 Gels 8/18/- CL- 24000 FC 2/- SOL 15.3 SD 0.50 OIL 1.0/82.0 MBL 10.0 pH 8.9 Ca+ 240 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION 0 file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS /MY WELLS/CHEVRON_ALASKA/20090312.htm (1 of 2)3/16/2009 2:06:38 AM Daily Report LITHOLOGY PRESENT THOLOGY ILY ACTIVITY Circ to get even MW @ 11.9; back ream out of SUMMARY hole. EPOCH PERSONNEL ON 2 DAILY $4075.00 BOARD COST C. REPORT BY Medlyn • file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS/MY WELLS /CHEVRON_ALASKA/20090312.htm (2 of 2)3/16/2009 2:06:38 AM Daily Report Ail Chevron USA lir Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR S. Lawrence /B. Rasch DATE Mar 17, 2009 DEPTH 10160' PRESENT OPERATION Running liner TIME 02:OOam YESTERDAY 10160' 24 HOUR FOOTAGE 0' CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM MP PRESSURE @ @ PSI IIIFILLING MUD REPORT DEPTH 10160' MW 11.8 VIS 60 PV 18 YP 20 FL 4.6 Gels 7/16/21 CL- 24000 FC 1/- SOL 15.3 SD 0.5 OIL 1.0/82.0 MBL 10.0 pH 8.6 Ca+ 240 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION I file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS/MY WELLS /CHEVRON_ALASKA/20090312.htm (1 of 2)3/17/2009 1:55:27 AM Daily Report LITHOLOGY PRESENT HOLOGY ILY ACTIVITY POOH after clean -out run; rig up wireline; unsuccessful on running wireline; rig up for liner; begin SUMMARY running liner. EPOCH PERSONNEL ON 2 DAILY 4075.00 BOARD COST C. REPORT BY Medlyn S • file: / / /C/DOCUMENTS AND SETTINGS/RIGUSER/M...UMENTS /MY WELLS /CHEVRON_ALASKA/20090312.htm (2 of 2)3/17/2009 1:55:27 AM Daily Report Chevron USA Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR D. Fowler /B. Rasch DATE Mar 18, 2009 DEPTH 10160' PRESENT OPERATION Rigging up to cement liner TIME 01:50:45 YESTERDAY 10160' 24 HOUR FOOTAGE 0' CASING 9.625" @ 7" @ INFORMATION 3000' 6120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM O MP PRESSURE @ @ PSI I ILLING MUD REPORT DEPTH 10160' MW 11.7 VIS 57 PV 18 YP 18 FL 4.7 Gels 6/16/21 CL- 22000 FC 1/- SOL 15.4 SD 0.25 OIL 1.0/82.0 MBL 10.0 pH 8.2 Ca+ 240 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION • file: / / /Cj/DOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS/MY WELLS /CHEVRON_ALASKA/20090312.htm (1 of 2)3/18/2009 1:49:26 AM Daily Report LITHOLOGY PRESENT ' HOLOGY ILY ACTIVITY Finish rigging up liner; run in with DP; circulate at 6048'; liner would not pass beyond 9123'; rigging up SUMMARY to cement in place. EPOCH PERSONNEL ON 2 DAILY $4075.00 BOARD COST C. REPORT BY Medlyn • file: / / /C[/DOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS /MY WELLS/CHEVRON_ALASKA/20090312.htm (2 of 2)3/18/2009 1:49:26 AM Daily Report Chevron USA Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR D. Fowler /B. Rasch DATE Mar 19, 2009 DEPTH 10160' PRESENT OPERATION Laying down drill pipe; cleaning out mud pits TIME 03:OOam YESTERDAY 10160' 24 HOUR FOOTAGE ' CASING 9.625" @ 7" @ INFORMATION 3000' 6120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM MP PRESSURE @ @ PSI ILLING MUD REPORT DEPTH 10160' MW 8.5 VIS 28 PV YP FL Gels CL- FC SOL 0.8 SD OIL -/99 MBL pH 8.6 Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS /MY WELLS/CHEVRON_ALASKA/20090312.htm (1 of 2)3/19/2009 3:06:53 AM Daily Report LITHOLOGY PRESENT • HOLOGY ILY ACTIVITY Cemented liner; flush well with water; begin to L/D drill SUMMARY pipe. EPOCH PERSONNEL ON 2 DAILY $4075.00 BOARD COST C. REPORT BY Medlyn 0 file: / / /Cl/DOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS/MY WELLS /CHEVRON_ALASKA/20090312.htm (2 of 2)3/19/2009 3:06:53 AM Daily Report Chevron USA Stump Lake Unit DAILY WELLSITE REPORT EPOCH LOGO SLU 41 -33RD REPORT FOR D. Fowler /B. Rasch DATE Mar 20, 2009 DEPTH 10160' PRESENT OPERATION Running heater string TIME 01:30am YESTERDAY 10160' 24 HOUR FOOTAGE 0' CASING 9.625" @ 7" @ INFORMATION 3000' 6120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM MP PRESSURE @ @ PSI ILLING MUD REPORT DEPTH 10160' MW 8.5 VIS 28 PV YP FL Gels CL- FC SOL SD 0.10 OIL 99.0/- MBL pH 8.8 Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION file: / / /CVDOCUMENTS AND SETTINGS/RIGUSER /M...UMENTS /MY WELLS /CHEVRON_ALASKA/20090312.htm (1 of 2)3/20/2009 1:16:32 AM Daily Report LITHOLOGY PRESENT HOLOGY ILY ACTIVITY Complete laying down of drill pipe; run production liner; continue emptying pits; R/U to run heater string; SUMMARY M/U and run heater string. EPOCH PERSONNEL ON 2 DAILY $4075.00 BOARD COST C. REPORT BY Medlyn • • file: / / /G/DOCUMENTS AND SETTINGS /RIGUSER/M...UMENTS /MY WELLS/CHEVRON_ALASKAJ20090312.htm (2 of 2)3/20/2009 1:16:32 AM