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207-120
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS F1 S; 4e' AL; V 9.'i..% JUN U 3 2019 A()C`rf` 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate LJ Pull Tubing LlLJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Installed SSC-SSSV (K Valve) ❑✓ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development Q Exploratory ❑ Stratigraphic ❑ Service ❑ 207-120 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20552-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 / ADL0018730 Trading Bay Unit M-17 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A McArthur River Field / Middle Kenai Gas Pool 11. Present Well Condition Summary: Total Depth measured 7,670 feet Plugs measured 5,040 feet true vertical 6,380 feet Junk measured N/A feet Effective Depth measured 5,040 feet Packer measured 1,390; 4,98P, 5,472 feet true vertical 4,096 feet true vertical 1.388; 4.044; 4.471 feel Casing Length Size MD TVD Burst Collapse Structural Conductor 485' 28" 485' 484' Surface 895' 13-3/8" 895' 894' 5,020 psi 2,260 psi Intermediate 1,430' 9-5/8" 1,430' 1,403' 5,750 psi 3,090 psi Production 5,700' 7" 5,700' 4,669' 7,240 psi 5,410 psi Liner 2,165' 5" 7,637' 6,350' 9,910 psi 10,500 psi Perforation depth Measured depth 3,216-4,860 feet True Vertical depth 2,613 - 3,940 feet 1,415 (MD) 1,390 (TVD) Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.21 L-80 5,098 (MD) 4,146 (ND) Packers and SSSV (type, measured and true vertical depth) See Schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: NIA 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 6667 0 260 290 1 Subsequent to operation: 0 6402 0 312 290 14. Attachments (required Per 20 AAC 25o70.25.071. a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory ❑ Development E] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas WDSPL Printed and Electronic Fracture Stimulation Data ❑ 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 NIA if C.O. Exempt: 319-241✓ Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmad(aihcom oweil.com Authorized Signature: � e'/er. Date: 6 Ps /71111Contact Phone: (907) 283-1329 Form 10-404 Revised 4/2017 6 We/ RSDMS-�MIUN p 3 2019 Submit Original Only K fI;14wro Alaska, LLC RKB to TBG Head 71.82' B V111� 28" Conductor ECP Stage Collar 13-3/8" in 1715" Hole ECP Stage Collar TOC @ 1,053' I b Hole in 12'6" Hole 52 Zone AZmw B & C Zone Top of tubing e @4,975' J® 8 C5 Zone 111 11x E C7Zone 9 VrJ" Lazing in 8 h" D3B Zone(sgzd plugged) D4 Zone D4 Zone Top of D6 Zone Primary Cement A Is7034' D14Zone 0 Top of Cement Plug at D16A Zone (sgxd plugged) rn D16C Zone (sozd olueeedl D17 Zone (plugged) V Potl-set pin at9413' w/ 15.23 5" Liner Shoe at 7637' gals ant placed w/ dump hailer 6-1/8"Hole TD at 7670' ROC cadged at 705' EIM, 213,08) MAX HOLE ANGLE: 56.40 @ Tangent 2,796' MD SCHEMATIC CASING DETAIL McArthur River Field Steelhead Platform Well M-17 Completed: 11/22/2015 SIZE WT GRADE CONN MIN ID TOP BTM(MDrkb) 28" Date Structural 27 Surface 485' 13-3/8" 68 L-80 BTC 12.415 Surface 895' 9-5/8" 4D L-80 BTC 8.835 Surface 1,430' 7" 26 L-80 ETC -106.276 Surface 5,7001 5- liner 18 L-80 H513 4.180' 5472' 7,637 1,362' 1,343' 5.00" TUBING DETAIL GLM 4,454'-4,480' 3-1/2" 9.2 L-80 TC -II 2.992 Surf 1,415- 3-1/2- 9.2 L-80 TC -II 1992 4,975' 5,098' *Tm 5°, 18a, FJ liner has an ID of 4.276" & drift of 4.155". The H513 connection has a 4.194" machined pin ID. The Baker UP Flex III hanger packer assembly has a TKC x H513 %over with a 4.180" machined to. This represents the minimum ID in the 5" liner. Top Fah: Oebrr from 5" drillable bridge plugs. Bottom Flan 2.5X15' Spiral Jet D gun, 1-11/16" x Is firing head, 1-11/16" x 1.5' magnet, 1-11/16" x VOCAL, 1-11/16" x 1'swivel,1-11/16" x IB' weight bar, 1-3/8" x 22' rope socket. lewelry Detail No. Depth (MD) Depth (TVD) OD ID Item Notes Date 454' 454' Notes 3,216'-3,232' 133/8x28" ECP Stage Collar Cemt'd to Surf SZ -23 849' 849' 3,535'-3,550' 2,823'-2,833' 95/8x133/8 ECP Stage Collar Attempt to Cemt to ML 6 408' 408' 2,853'-2,865' 12/17/2015 SSC-SSSV 6 1 414' 414' 5.375" 2.813" SSSV 2 1,362' 1,343' 5.00" 2.813" GLM 4,454'-4,480' 3 1,390' 1,368' 5.870' 3.00" ASI -X Retrievable Packer 3,926'-3,940' 4 1,406' 1,382' 4.50" 2.813" X -Nipple 06/18/2012 5 1,415' 1,390' 4.50" 2.992" WLEG C-7 6 4,980' 4,044' 5.97" 3.900° Production Packer Baker S-3 7 5,040' 4,096' 4.50" 2.813" X Profile Nipple w/X-Plug Squeezed, 112.5 bbls 15.8 ppg DCT 8 5,098' 4,146' 3.93" 2.960" WLEG(bottom) 6,066'-6,073' 9 5,472' 4,471' 5.250" 4.180' ZKP Flex 111 Hanger Packer 5,078'-5,086' 10 7,213' 5,9801 11>> - 5" Cement Retainer Top of Cement at 7,2001 N/A 6 Squeezed, Ref SCMT Log 11/22/07 7,142'-7,155' 5,919'-5,930' 04/05/2010 D-14 Note: Placed 2' of ceramic beads on top of sand fill @ 5,297'. Dump Bailed 19' Neo #17 Cement over the ceramic beads. Revised: 05/31/19 by 1LL Perforation Detail MD Tv0 Date Zone (SPF) Notes 3,216'-3,232' 2,613'-2,623' 08/30/2017 SZ -23 5 Open 3,535'-3,550' 2,823'-2,833' 10/29/2016 A-3 6 3,577'-3,592' 2,853'-2,865' 12/17/2015 A-3 6 3,981'-3,988' 3,179'-3,185' 12/16/2015 A-6 6 4,440'-4,447' 3,576'-3,582' 12/07/2016 8-3 5 Open 4,454'-4,480' 3,589'-3,611' 12/07/2016 B-3 5 Open 4,844'-4,860' 3,926'-3,940' 12/06/2016 C-1 5 Open 5,147'-5,167' 4,189'-4,206' 06/18/2012 C-5 6 Isolated 5,229'-5,236' 4,260'-4,266' 06/15/2012 C-7 4 Isolated 5,782'-5,788' 4,740'-4,745' 11/29/2007 N/A 6 Squeezed, Ref SCMT Lag 11/22/07 5,832'- 5,856' 4,784'-4,805' 02/19/2008 D-38 5 Squeezed, 112.5 bbls 15.8 ppg DCT 6,029'-6,042' 4,955'-4,967' 06/01/2012 D-4 4 2-1/2" Shogun Strip 60 deg Spiral Strip 6,066'-6,073' 4,988'-4,994' 06/01/2012 D-4 4 2-1/2" Shogun Strip 60 deg Spiral Strip 6,169'-6,179' 5,078'-5,086' 06/01/2012 0-6 4 2-1/2" Shogun Strip 60 deg Spiral Strip 6,234'-6,240' 5,135'-5,140' 11/27/2007 N/A 6 Squeezed, Ref SCMT Log 11/22/07 7,142'-7,155' 5,919'-5,930' 04/05/2010 D-14 6 SLB 2-1/2" PJ Omega HC 60o phasing 7,296'-7,308' 7,361' - 7,391' 6,052'-6,062' 6,108' -6,135' 02/16/2008 02/13/2008 D -16A D -16C 6-11 6-11 Plugged/Squeezed thru cement retainer at 7213' with 3.25 bills of LXT cement and 2 this dumped on top and dressed to 7200' 7,456'-7,470' 6,191'-6,204' 12/21/2008 D-17 11 Isolated with5"Poli-Set Plug at 7423' and 15.25 gals (18') of dump bailed cement. Note: Placed 2' of ceramic beads on top of sand fill @ 5,297'. Dump Bailed 19' Neo #17 Cement over the ceramic beads. Revised: 05/31/19 by 1LL Hilcorp Alaska, LLC Well Operations Summary Well Name Rig AP1 Number Well Permit Number Start Date End Date M-17 W/Line 1 50-733-20552-00 1 207-120 5/18/19 1 5/18/19 Daily Operations: 05/18/19 -Saturday ARRIVE AT PWL - GATHER TOOLS AND PERSONNEL - MOB TO OSK. FLIGHT TO STEELHEAD. TGSM - JSA - PERMIT. RIG UP W/L - PT LUB 250/1500 PSI - PASS. RIH W/ 2.9" BRAIDED LINE BRUSH TO 425'KB. BRUSH TUBING - POOH. RIH W/ 3" GS W/ PB VALVE W/ WEATHERFORD PACK OFF AND 2.85" GAUGE RING - CAN NOT PASS CROSS OVER AT SURFACE - POOH. RIH W/ SAME - CAN NOT PASS XO - POOH. RIH W/ 2.84" GAUGE RING - PASS XO - RUN TO 425'KB TAG X PROFILE ABOVE SSSV - POOH. RIH W/ 3" GS W/ PB VALVE W/ WEATHERFORD PACK OFF AND 2.84" GAUGE RING TO 425'KB WT. SET VALVE - POOH. OOH W/ SHEARED GS. RIH W/ 3" GS W/ 3 1/2 A STOP TO 419'KB WT SET STOP - POOH - OOH SHEARED GS. STANDBY FOR PRODUCTION TO PERFORM CLOSURE TEST. CLOSURE TEST FAILED. RIH W/ 3" GS TO 419'KB WT LATCH A -STOP - POOH - OOH W/ A STOP IN GOOD ORDER. RIH W/ 3" GS TO 420'KB WT LATCH PB VALVE - POOH - OOH W/ PB VALVE - PACK OFF IN GOOD CONDITION. SEND PB VALVE TO TOWN TO BE RESET AT HIGHER PRESSURE - STANDBY. RIH W/ 3" GS W/ PB VALVE TO 425'KB WT SET VALVE - POOH - OOH GS SHEARED, RIH W/ 3" GS W/ A -STOP TO 419'KB SET STOP - POOH - OOH W/ SHEARED GS. RIG DOWN W/L - SECURE WELL - PRODUCTION TO PERFORM CLOSURE TEST, PASSED. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Stan Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai Gas Pool, TBU M-17 Permit to Drill Number: 207-120 Sundry Number: 319-241 Dear Mr. Golis: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.olaska.gov Enclosed is the approved application for the 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, Daniel T. Seamount, Jr. Commissioner DATED this 144of May, 2019. 3BDMSLi�- MAY 15 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 90 AAc 9F 9RO RECEIVED MAY 10 2019 Ann- r 1. Type of Request: Abandon ❑ Plug Perforations ElFracture Stimulate ❑ Repair Well ElOperations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Install SSC-SSSV ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development 0 Stratigraphic ❑ Service ❑ 207-120 ' 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20552-00-00 ' 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 ❑ No Trading Bay Unit M-17 - 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0017594 / ADL0018730 McArthur River Field / Middle Kenai Gas Pool 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): 7,670 - 6,380 5,040 4,096 858 psi 5,040 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 485' 28" 485' 484' Surface 895' 13-3/8" 895' 894' 5,020 psi 2,260 psi Intermediate 1,430' 9-5/8" 1,430' 1,403' 1 5,750 psi 3,090 psi Production 5,700' 7" 5,700' 4,669' 1 7,240 psi 5,410 psi Liner 2,165' 5" 17,637' 6,350' 9,910 psi 10,500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3,216 - 4,860 2,613 - 3,940 3-1/2" 9.2# / L-80 1,415 8 5,098 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): ASI -X Ret Pkr, Prod Pkr, ZXP Flex III Hgr Pkr & SSSV 1,390' (MD) 1,368' (TVD), 4,980' (MD) 4,044' (TVD), 5,472' (MD) 4,471' (ND) 8 414' (MD) 414' (TVD) 12. Attachments: Proposal Summary Wellbore schematic = 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/24/2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑Q WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dirrarlowe0hilcorlD.COM r / Contact Phone: (907) 283-1329 �/ � d Authorized Signature: /fir+ J Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative ma witness Sundry Number: 5SC-Sas UI �0 `I L u t, rt Plug Integrity ❑ Test ❑ 111s� Location Clearance ElAe /BOP ^-� Other: # ! � c T ; � r`.""`� �eZ 1 a ' .s`.a"'^L 4" S TO �' �_ Il 0 Post Initial Injection MIT Req'd? Yes ❑ No ❑ �,/ Spacing Exception Required? Yes ❑ No Subsequent Form Required: / V -- / 09 RBDMSIL�MAY 15 2019 4�4�e APPROVED BY Approved by COMMISSIONER THE COMMISSION Date / Submd Form andS3s In pproved applicatiForm 10-40Rvise4vsRhiiA he date of approval./�hachments in Duplicate � SGS /� 5 !v,/9 K nil orp Akuka, LLC Well Work Prognosis Well Name: TBU M-17 API Number: 50-733-20552-00-00 Current Status: Gas Well Leg: Leg A-1 Estimated Start Date: May 24, 2019 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Received: Regulatory Contact: Juanita Lovett Permit to Drill Number: 207-120 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Second Call Engineer: Stan Golis Office: 907-777-8356 Current Bottom Hole Pressure: 615 psi @ 2,823' TVD 0.218 psi/ft based on SIBHP Maximum Expected BHP: 615 psi @ 2,823' TVD 0.218 psi/ft based on SIBHP Maximum Potential Surface Pressure: 858 psi Using 0.1 psi/ft gradient per 20 AAC 25.280(b)(4) Brief Well Summary The M-17 SSSV was damaged during wireline work May 6, 2019. An in-house test on May 7, 2019 indicates the valve is operational but fails to fully seal. This project will install a subsurface controlled subsurface safety valve (SSC-SSSV) in accordance with Guidance Bulletin 10-004. SSC-SSSV Suitability Evaluation: Well historic parameters Gross Gas 7 mmcfd FTP 300 psig Temp 53F This safety valve will be setup with a trip pressure of -125 psig. We will hold backpressure on the well with the production choke to maintain a normal FTP of ^300 psig. To test the valve we will either close the tubing conveyed SSSV or open the automated control valve, either will lower the FTP and trip the SC-SSSV. To reset the valve the control valve will be closed and well pressured up to above the trip pressure then gradually reopened to the normal operating range. Procedure: 1. MIRU Slick -line, PT lubricator to 1,500 psi Hi 250 Low. 2. RIH and set the subsurface controlled subsurface safety valve. 3. Turn well over to production. 4. Conduct a SVS test within 5 days after stabilized flow. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. McMurry-Macco PB Subsurface Safety valve cut sheet. (Alternate Halliburton K -valve may also be used depending on availability) K tlileorp Alaska. LLC RKB to TBG Head 71.82' 28"Conductor I, ECP Stage Collar 13-3/8' in 17 K' Hole ECP Stage Collar TOC @ 1,053' d - I, GRADE - 9-5/8" in 128" TOP Hole 3 Date Structural x Surface 485' 133/8x28" ECP stage Collar SZ Zone SZ -23 A Zone 849' B & C Zone [1U3-3/r68L-80 Topoftubing L-80 @ 4,975' 414' 7 5375' B C5Zone SSSv TOC -,276 C7Zone 2 7" Casing In 8 X" 1,343' D3B Zone (sgzd plugged( W Zone D4 Zone Top of D6 Zone Primary Cement is 7034' 014ZOne Top of Cement Plug at n D36A Zane (sgzd plugged) D16CZone (sazd olueeedl 017 Zen. (Plugged) 5" Vos45et 11,.17423'./ 15.23 5" Liner Shoe at 7637' eats mit placed w/dump bailer 61/8" Hole TD at 7670' Toc to&ed at 7405'ELIa, 2-1w) MAX HOLE ANGLE: 56.4" @ Tangent 2,796' MD SCHEMATIC CASING DETAIL McArthur River Field Steelhead Platform Well M-17 Completed: 11/22/2015 *The 5", 18g, FJ liner has an ID of 4.276" & drift of 4.155". The H513 connection has a 4.194" machined pin ID. The Baker ZXP Flex III hanger packer assembly has a TKC x H513 X over with a 4.180" machined ID. This represents the minimum ID in the 5" liner. Tap Fish: Debris from 5" drillable bridge plugs. Bottom Fish: 2.5X15' Spiral Jet D gun, 1-11/16" x 1.5 firing head, 1-11/16" x 1.5' magnet, 1-11/16' x 1' CCL, 1-11/1V x V swivel, 1-11/16" x 18' weight bar, 1-31V x 22' ripe socket. Jewelry Detail No. Depth (MD) GRADE CONNM1,2.415 TOP BTM (MDrkb) Notes Date Structural 454' Surface 485' 133/8x28" ECP stage Collar Cemt'dtosurf SZ -23 BTCSurface 849' 895' [1U3-3/r68L-80 95/8x133/8 ECP Stage Collar L-80 RTCSurface 414' 1,430' 5375' 2.813" SSSv TC-MSurface 2 5,700' 1,343' SnV L-80 H5135472' 7,637' 1,390' 1,368' 5.870" TUBING DETAIL ASI -X Retrievable Packer 4,454'-4,480' 3-1/2" 9.2 L-80 TC -II 2.992 surf 1,415' 3-1/2" 9.2 L-80 TCiI 2.992 4,975' 5,098' *The 5", 18g, FJ liner has an ID of 4.276" & drift of 4.155". The H513 connection has a 4.194" machined pin ID. The Baker ZXP Flex III hanger packer assembly has a TKC x H513 X over with a 4.180" machined ID. This represents the minimum ID in the 5" liner. Tap Fish: Debris from 5" drillable bridge plugs. Bottom Fish: 2.5X15' Spiral Jet D gun, 1-11/16" x 1.5 firing head, 1-11/16" x 1.5' magnet, 1-11/16' x 1' CCL, 1-11/1V x V swivel, 1-11/16" x 18' weight bar, 1-31V x 22' ripe socket. Jewelry Detail No. Depth (MD) Depth (TVD) DD ID Item Notes Date 454' 454' Notes 3,216'-3,232' 133/8x28" ECP stage Collar Cemt'dtosurf SZ -23 849' 849' 3,535'-3,550' 2,823'-2,833' 95/8x133/8 ECP Stage Collar Attempt to Cannot to ML 1 414' 414' 5375' 2.813" SSSv 6 2 1,362' 1,343' SnV 2.813" GLM 3 1,390' 1,368' 5.870" 3.00' ASI -X Retrievable Packer 4,454'-4,480' 4 1,406' 1,382' 4.50" 2.813" X -Nipple 3,926'-3,940' 5 1,415' 1,390' 4.50" 2.992" WLEG 06/18/2012 6 4,980 4,044' 5.97" 1 3.900" 1 Production Packer 1 Baker S-3 4 060'5, 4,096' 4.50" 2.813" XProfile Nipple w/X-Plug 6 Squeezed, Ref SCMT Log 11/22/07 5,098' 4,146' 3.93" 2.960" WLEG fbottom) Squeezed, 112.5 bbls 15.8 ppg LXT Va7 5,472' 4,471' 1250" 4.180" 2XPFIeX 111 Hanger Packer 6,066'-6,073' 4,988'-4,994' 7,213' 5,980' 4 »» 5" Cement retainer Top of Cement at 7,200' 06/01/2012 D-6 4 2-1/2" Shogun Strip 60 deg Spiral Strip 6,234'-6,240' 5,135'-5,140' 11/27/2007 Note: Placed 2' of ceramic beads on top of sand fill @ 5,297'. Dump Bailed 19' Neo #17 Cement over the ceramic beads. Revised: 09/25/17 by 1LL Perforation Detail MD TVD Date Zone (SPF) Notes 3,216'-3,232' 2,613'-2,623' 08/30/2017 SZ -23 5 Open 3,535'-3,550' 2,823'-2,833' 10/29/2016 A-3 6 3,577'-3,592' 2,853'-2,865' 12/17/2015 A-3 6 3,981'-3,988' 3,179'-3,185' 12/16/2015 A-6 6 4,440'-4,447' 3,576'-3,582' 12/07/2016 B-3 5 Open 4,454'-4,480' 3,589'-3,611' 12/07/2016 8-3 5 Open 4,844'-4,860' 3,926'-3,940' 12/06/2016 C-1 5 Open 5,147'-5,167' 4,189'-4,206' 06/18/2012 C-5 6 Isolated 5,229'-5,236' 4,260'-4,266' 06/15/2012 C-7 4 Isolated 5,782'-5,788' 4,740'-4,745' 11/29/2007 N/A 6 Squeezed, Ref SCMT Log 11/22/07 5,832' - 5,856' 4,784' -4,805' 02/19/2008 D -3B 5 Squeezed, 112.5 bbls 15.8 ppg LXT 6,029'-6,042' 4,955'-4,967' 06/01/2012 D-4 4 2-1/2" Shogun Strip 60 deg Spiral Strip 6,066'-6,073' 4,988'-4,994' 06/01/2012 D-4 4 2-1/2" Shogun Strip 60 deg Spiral Strip 6,169'-6,179' 5,078'-5,086' 06/01/2012 D-6 4 2-1/2" Shogun Strip 60 deg Spiral Strip 6,234'-6,240' 5,135'-5,140' 11/27/2007 N/A 6 Squeezed, Ref SCMT Log 11/22/07 7,142'-7,155' 5,919'-5,930' 04/05/2010 D-14 6 SLB 2-1/2" P10mega HC 60o phasing 7,296'-7,308' 7,361'-7,391' 6,052'-6,062' 6,108'-6,135' 02/16/2008 02/13/2008 D -16A D -16C 6-11 6-11 Plugged/Squeezed thru cement retainer at 7213'with 3.256bls of LXT cement and 2 bbls dumped on top and dressed to 7200' 7,456'-7,470' 6,191'-6,204' 12/21/2008 D-17 IS Isolated with 5"Poll-Set Plug at 7423' and 15.25 gals (18') of dump bailed cement. Note: Placed 2' of ceramic beads on top of sand fill @ 5,297'. Dump Bailed 19' Neo #17 Cement over the ceramic beads. Revised: 09/25/17 by 1LL McArthur River Field StePlatform PROPOSED Wellll M-1 M-17 IIilcorp Alaldca, LLC Completed: 11/22/2015 CASING DETAIL RKB to TBG Head 71.82' 3 28" Conductor ECP Stage Collar 13-3/8" in 17 X" Hole ECP Stage Collar SIZE Depth (MD) Depth (ND) CONN MIN ID TOP BTM (MDrkb) 28" Date 454' 27 Surface 485' 13-3/8" Cemrdto5urf KQL�o BTC 12.415 Surface 895' 9-5/8" 95/8x133/8 ECP Stage Collar Attempt to Cemtto ML BTC 8.835 Surface 1,430' 7" 2.813" SSC-SSSv BTC -M 6.276 Surface 5,700'H513 414' 5.375" 1913' 4.180• 5472' ],63T 1,362' 1,343' 5.00" TUBING DETAIL GIM 4,454'-4,480' 3-1/2" 9.2 L-80 TC -II 2.992 Surf 1,415' 3-1/2' 9.2 L -8a TC -II 2.992 4,975' 5,098' "The 5", Lee, FJ liner has an ID of 4.276" & drift of 4.155". The H513 connection has a 4.194" machined pin ID. The Baker ZXP Flex III hanger TOC @1,053' packer assembly has a TKC x H513 Over with a 4.113W machined ID. This represents the minimum ID in the 5" liner. Top Fish: Debris foam 5" drillable bridge plugs. Bottom Fish: 2.5X15' Spiral let 0 Sun, 141/16' x 1.5 firing head, 1-11/16* x 1.5' magnet, 1-11/16"x 1' CCL, 1-11/16" x 1'swlvel,1-11/16" x 18' weight bar, 1-3/8" x 22'rope socket. 9-5/8" in 12 W Hole n SZZpne A Zone B&C Zone Top of tubing @4,975' C5Zone C7 Zone v 7" Casing In 8:5' D3B Zone (sgzd plugged) D4 Zone 04 Zone Top of D6 Zone Primary Cement is 7034' D34 Zone Top of Cement Plug at O DIRA Zone (sgzd plugged) DSfiC Zone (spzd olueead) D17 Zone (Plugged) Y Posl'Set plug at 7423' w/ 15.23 5- Liner Shoe at 7637' gals cmt placed w/ dump bailer 6-1/8" Hole M at 7670' nouaased at 705' 1., 111-e81 MAX HOLE ANGLE: 56.4' @ Tangent 2,796' MD Jewelry Detail No. Depth (MD) Depth (ND) OD ID Item Notes Date 454' 454' Notes 3,216'-3,232' 133/8x28" ECP Stage Collar Cemrdto5urf SZ -23 849' 849' 3,535'-3,550' 2,823'-2,833' 95/8x133/8 ECP Stage Collar Attempt to Cemtto ML 6 3410' x410' 2,853'-2,865' 2.813" SSC-SSSv 6 1 414' 414' 5.375" 1913' SSSV 2 1,362' 1,343' 5.00" 2.813" GIM 4,454'-4,480' 3 1,3910' 1,368' 5.870" 3.00" ASI -X Retrievable Packer 3,926'-3,940' 4 1,406' 1,382' 4.50" 2.813" X -Nipple 06/18/2012 5 1,415' 1,390' 4.50" 2.992" WLEG C-7 6 4,980' 4,044' 5.97" 3.900" Production Packer Baker 5-3 7 5,040' 4,096 4.50" 2.813" X Profile Nipple w/X-Plug Squeezed, 112.5 bbls 15.8 ppg LXT 8 5,098' 4,146' 3.93" 2.960" WLEG(bottom) 6,066'-6,073' 9 5,472' 4,471' 5.250" 4.18D" ZXP Flex III Hanger Packer 5,078'-5,086' 10 7,213' 5,980' »» »» 5" Cement Retainer Top of Cement at 7,200' N/A 6 Squeezed, Ref SCMT Log 11/22/07 7,142'-7,155' 5,919'-5,930' 04/05/2010 D-14 Note: Placed 2' of ceramic beads on top of sand fill @ 5,297'. Dump Bailed 19' Neo #17 Cement over the ceramic beads. Revised: 05/09/19 by JLL Perforation Detail MD TVD Date Zone (SPF) Notes 3,216'-3,232' 2,613'-2,623' 08/30/2017 SZ -23 5 Open 3,535'-3,550' 2,823'-2,833' 10/29/2016 A-3 6 3,577'-3,592' 2,853'-2,865' 12/17/2015 A-3 6 3,981'-3,988' 3,179'-3,185' 12/16/2015 A-6 6 4,440'-4,447' 3,576'-3,582' 12/07/2016 B-3 5 Open 4,454'-4,480' 3,589'-3,611' 12/07/2016 B-3 5 Open 4,844'-4,860' 3,926'-3,940' 12/06/2016 C-1 5 Open 5,147'-5,167' 4,189'-4,206' 06/18/2012 C-5 6 Isolated 5,229'-5,236' 4,260'-4,266' 06/15/2012 C-7 4 Isolated 5,782'-5,788' 4,740'-4,745' 11/29/2007 N/A 6 Squeezed, Ref SCMT Log 11/22/07 5,832' - 5,856' 4,784'-4,805' 02/19/2008 D -3B 5 Squeezed, 112.5 bbls 15.8 ppg LXT 6,029'-6,042' 4,955'-4,967' 06/01/2012 D4 4 2-1/2" Shogun Strip 60 deg 5 piral Strip 6,066'-6,073' 4,988'-4,994' 06/01/2012 04 4 2-1/2" Shogun Stri p 60 deg 5 piral Strip 6,169'-6,179' 5,078'-5,086' 06/01/2012 D-6 4 2-1/2" Shogun Strip 60 deg Spiral Strip 6,234'-6,240' 5,135'-5,140' 11/27/2007 N/A 6 Squeezed, Ref SCMT Log 11/22/07 7,142'-7,155' 5,919'-5,930' 04/05/2010 D-14 6 SLB 2-1/2" PJ Omega HC 600 phasing 7,296'-7,308' 7,361'-7,391' 6,052'-6,062' 6,108'-6,135' 02/16/2008 02/13/2008 D -16A D-I6C 6-11 6-11 Plugged/Squeezed thru cement retainer at 7213'with 3.25 bbls of LXT cement and 2 bbls dumped on topand dressed to 7200' 7,456'-7,470' 6,191'-6,204' 12/21/2008 D-17 IS Isolated with 5" PoskSet Plug at 7423'and 25 gals 15. (I8') of dump bailed cement. Note: Placed 2' of ceramic beads on top of sand fill @ 5,297'. Dump Bailed 19' Neo #17 Cement over the ceramic beads. Revised: 05/09/19 by JLL McMurry-Macco McMurry-Macco PB Subsurface Safety Valve Advantages • Large flow area. • No flow through moving parts of safety valve. • No hydraulic seals. Closing force is transmitted through liquid -filled bellows. • Predictable and repeatable valve performance. • Snap -action closure. Valve disc does not throttle in flow stream. • Suitable for gas lift wells. • Easily field tested. With use of a convenient test stand, the PB safety valve can be tested and reset. • No depth limitation. The PB is suitable for a wide variety of special applications. The PB is wireline retrievable and can be sus- pended and packed off in any standard landing nipple with the appropriate locking device. The PB can also be suspended and packed off in the tubing string with a collar lock mandrel. The PB is available in a 50 to 3,000 psi range (PB) and a 100 to 10,000 psi range (HP -PB). Features • Subsurface control. • Wireline retrievability. • 50 to 10,000 psi operating range. • Bellows protection unit. • Positive closing pressure. • Hard and soft disc -seat closing seal. API 14A, ASME SPPE-1 specifications and are available for class I, or 3S service. *01 >—NITON ELASTOMERS All elastomers are made of Viton. IR VI TON SEAT —Disc 17-4 ph stainless steel 17-4 ph stainless steel SEAL LOCKING SLEEVE Holds locking balls in lock groove. SENSING PORT :h screens 1d sand. ITECTION UNIT overextension. DOME Contains nitrogen charge PLUG a up dome check valve. LOCKING BALLS Hold disc in open position ING g farce. RECOCKING SPRING TRIP RING Pushes locking sleeve up to release disc. r, 21W141 RITITM VALVE with 10,000,000 1,000,000 100,000 10,000 1,000 100 10 1 Jan -2006 HILCORP ALASKA LLC, TRADING BAY UNIT M-17 (207-120) MCARTHUR RIVER, MIDKENAI GAS Monthly Production Rates Jan -2008 Jan -2010 Jan -2012 Jan -2014 Jan -2016 Jan -2018 Produced Gas iMCFM) GOR • Produced Water (aOPM) --o- Produced Oil (BOPM) 10,000,000 1,000,000 100,000 10,000 1,000 100 10 1 Jan -2020 SPREADSH EET_2071200_TBU_M-17_Prod-I nject_Cu wes_W el I_Gas_V120_20190510.x1sx 5/10/2019 * STATE OF ALASKA ALAIIPA OIL AND GAS CONSERVATION COMMMION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown 0 Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 207-120 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service 0 6.API Number: Anchorage,AK 99503 50-733-20552-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: i (Lf� IVE ADL0017594/ADL0018730 Trading Bay Unit M-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): ; � r� 07 N/A McArthur River Field/Middle Kenai Gas Pool d 11.Present Well Condition Summary: AOGCC Total Depth measured 7,670 feet Plugs measured 5,040 feet true vertical 6,380 feet Junk measured N/A feet Effective Depth measured 5,040 feet Packer measured See Schematic feet true vertical 4,096 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor 485' 28" 485' 484' Surface 895' 13-3/8" 895' 894' 5,020 psi 2,260 psi Intermediate 1,430' 9-5/8" 1,430' 1,403' 5,750 psi 3,090 psi Production 5,700' 7" 5,700' 4,669' 7,240 psi 5,410 psi Liner 2,165' 5" 7,637' 6,350' 8,290 psi 7,250 psi Perforation depth Measured depth 3,216-4,860 feet True Vertical depth 2,613-3,940 feet 3-1/2" 9.2#/L-80 1,415(MD) 1,390(TVD) Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 5,098(MD) 4,146(TVD) Packers and SSSV(type,measured and true vertical depth) See Schematic 12.Stimulation or cement squeeze summary: Intervals treated(measured): DEC ., N/ SCANNED C 0 2017, 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 1034 0 48 32 Subsequent to operation: 0 4872 0 117 378 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development0 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 ❑ WAG ❑ GINJ❑ SUSP❑ SPLUGO 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: 317-346 ' Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarloweahilcora.com tEbAuthorized Signature: `'� (i4Date: Q fr (ZG t 1 Contact Phone: (907)283-1329 /0 '�PEDMS OCT - 32017 Form 10-404 Revised 4/2017 rO/ �' Submit Original Only McArthur River Field II 41110 SCHEMATIC • Steelhead Platform Well M-17 Hilcorp Alaska,LLC Completed: 11/22/2015 CASING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM(MDrkb) 28" Structural 27 Surface 485' RKB to TBG Head 71.82' 13-3/8" 68 L-80 BTC 12.415 Surface 895' 9-5/8" 40 L-80 BTC 8.835 Surface 1,430' £" 7" 26 L-80 BTC-M 6.276 Surface 5,700' 1 4 28"Conductor 5"liner 18 L-80 H513 4.180° 5472' 7,637' ECP Stage Collar TUBING DETAIL ilktr + 13-3/S"in 17 h"Hole 3-1/2" 9.2 L-80 TC-II 2.992 Surf 1,415' , ECP Stage Collar 3-1/2" 9.2 L-80 TC-II 2.992 4975' 5,098' "The 5",189,FJ liner has an ID of 4.276"&drift of 4.155". The H513 connection has a 4.194"machined pin ID.The Baker ZXP Flex III TOC @ 1,053' hanger packer assembly has a TKC x H513 X over with a 4.180"machined ID.This represents the minimum ID in the 5"liner. Top Fish:Debris from 5"drillable bridge plugs. Bottom Fish: 2.5X15'Spiral Jet EJ gun,1-11/16"x 1.5 firing head,1-11/16"x 1.5'magnet,1-11/16"x 1'CCL,1-11/16"x 1'swivel,1-11/16" x 18'weight bar,1-3/8"x 22'rope socket. 1 2 t7 '° 9-5/8"in 12'''4" i l t ,.., Hole Jewelry Detail 3 X No. Depth(MD) Depth two OD ID Item Notes 4 L Th' 454' 454' 13 3/8 x 28"ECP Stage Collar Cemt'd to Surf S 849' 849' 9 5/8 x 13 3/8 ECP Stage Collar Attempt to Cemt to ML ' A Zone 1 414' 414' 5.375" 2.813" SSSV B&C Zone 2 1,362' 1,362' 5.00" 2.813" GLM Top of tubing 3 1,390' 1,390' 5.870" 3.00" AS1-X Retrievable Packer 6 .u, @ 4,975' 4 1,406' 1,406' 4.50" 2.813" X-Nipple 7L' 5 1,415' 1,415' 4.50" 2.992" WLEG 8 = C5 Zone 6 4,980' 4,980' 5.97" 3.900" Production Packer Baker S-3 IOC 5,276 C7 Zone 7 5,040' 5,040' 4.50" 2.813" X Profile Nipple w/X-Plug 8 5,098' 5,098' 3.93" 2.960" WLEG(bottom) - 9 5,472' 5,472' 5.250" 4.180" ZXP Flex III Hanger Packer , IL_ »I10 7,213' 7,213' » »» 5"Cement Retainer Top of Cement at 7,200' t, , _e 7"Casing in 8'A" D3B Zone(sgzd plugged) Perforation Detail MD TVD Date Zone Notes °vcfi, (SPF) 3,216'-3,232' 2,613'-2,623' 08/30/2017 SZ-23 5 Open 3,535'-3,550' 2,823'-2,833' 10/29/2016 A-3 6 D4 Zone 3,577'-3,592' 2,853'-2,865' 12/17/2015 A-3 6 ' 3,981'-3,988' 3,179'-3,185' 12/16/2015 A-6 6 D4 Zone 4,440'-4,447' 3,576'-3,582' 12/07/2016 B-3 5 Open Top of ; D6 Zone 4,454'-4,480' 3,589'-3,611' 12/07/2016 B-3 5 Open Primary Cement 4,844'-4,860' 3,926'-3,940' 12/06/2016 C-1 5 Open Is 7034 5,147'-5,167' 4,189'-4,206' 06/18/2012 C-5 6 Isolated D14 Zone 5,229'-5,236' 4,260'-4,226' 06/15/2012 C-7 4 Isolated Top of Cement Plug at 5,782'-5,788' 4,740'-4,745' 11/29/2007 N/A 6 Squeezed,Ref SCMT Log 11/22/07 10 5,832'-5,856' 4,784'-4,805' 02/19/2008 D-3B 5 Squeezed,112.5 bbls 15.8 ppg LXT D16A Zone(sgzd plugged) 11 016C Zone(said olueeed) 6,029'-6,042' 4,955'-4,967' 06/01/2012 D-4 4 2-1/2"Shogun Strip 60 deg Spiral Strip 6,066'-6,073' 4,988'-4,994' 06/01/2012 D-4 4 2-1/2"Shogun Strip 60 deg Spiral Strip 017 Zone(plugged) 6,169'-6,179' 5,078'-5,086' 06/01/2012 D-6 4 2-1/2"Shogun Strip 60 deg Spiral Strip 4111 5"Posi-Set plug at 7423'w/15.23 6,234'-6,240' 5,135'-5,140' 11/27/2007 N/A 6 Squeezed,Ref SCMT Log 11/22/07 5"Liner Shoe at 7637' gals cmt placed w/dump bailer 7,142'-7,155' 5,919'-5,930' 04/05/2010 D-14 6 SLB 2-1/2"PJ Omega HC 60°phasing 6-1/8"Hole TD at 7670' (TOC tagged at 7405'ELM,2-11-08) 7,296'-7,308' 6,052'-6,062' 02/16/2008 D-16A 6-11 Plugged/Squeezed thru cement retainer at 7213'with 7,361'-7,391' 6,108'-6,135' 02/13/2008 D-16C 6-11 3.25 bbls of LXT cement and 2 bbls dumped on top and MAX HOLE ANGLE: dressed to 7200' 56.4°@ Tangent 2,796' MD 7,456'-7,470' 6,191'-6,204' 12/21/2008 D-17 11 Isolated with 5"Posi-Set Plug at 7423'and 15.25 gals (18')of dump bailed cement. Note:Placed 2'of ceramic beads on top of sand fill @ 5,297'. Revised:09/25/17 by JLL • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date M-17 E-Line 50-733-20552-00 207-120 8/30/17 8/30/17 DailyOperationsjF ., vAt 08/30/2017-Wednesday Guns arrived on M/V. Obtain work permits and rig up Eline equipment. PU lubricator with 1-11/16" gamma ray/CCL and 16' 2-3/8" (5spf) perf gun. (12' CCL to top shot). Stab onto well. PT lubricator 250psi/1500psi. RIH with well flowing 0.9mmscfd @ 30 psi FTP. Logged through BHA jewelry at 1400'. Logged correlation pass from 3330'-3170' and send to RE. Logged and confirmed (adjusted 1' uphole). Log into position w/CCL @ 3204' to perforate at 3216'- 3232'. Fired gun. Good indication of detonation. POOH. Well pressured up to 625psi. Pinched back to 1 mmscfd to POOH. OOH -All shots fired. RD Eline. Depart for OSK. • °F 7.4, • • • \Iyyy s THE STATE Alaska Oil and Gas � ►�a� OfA LAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 lie/ST7 Off, ,m* . Main: 907.279.1433 ALASY Fax: 907:276.7542 www.aogcc.alaska.gov Stan Golis SCANNEDI 1 12°17i Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai Gas Pool, M-17 Permit to Drill Number: 207-120 Sundry Number: 317-346 Dear Mr. Golis: 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, Hollis S. French 4 Chair DATED this - day of August, 2017. RBDMS AUG - 9 2017 111 i• RECEIVED STATE OF ALASKA i` ALASKA OIL AND GAS CONSERVATION COMMISSION ADCC APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 0— Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill El Perforate New Pool ❑ 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 0• 207-120 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20552-00-00 ` 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A - Will planned perforations require a spacing exception? Yes ❑ No 0 .1 Trading Bay Unit M-17 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594/ADL0018730 - McArthur River Field/Middle Kenai Gas Pool - 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): 7,670 . 6,380 5,040 * •4,096 839 psi 5,040 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 485' 28" 485' 484' Surface 895' 13-3/8" 895' 894' 5,020 psi 2,260 psi Intermediate 1,430' 9-5/8" 1,430' 1,403' 5,750 psi 3,090 psi Production 5,700' 7" 5,700' 4,669' 7,240 psi 5,410 psi Liner 2,165' 5" 7,637' 6,350' 8,290 psi 7,250 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 3,535-4,860 • 2,823-3,940 3-1/2" 9.2#/L-80 1,415&5,098 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): AS1-X Ret Pkr,Prod Pkr,ZXP Flex III Hgr Pkr&SSSV 1,390'(MD)1,368'(TVD),4,980'(MD)4,044'(TVD),5,472'(MD)4,471'(TVD)&414'(MD)414'(TVD) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 ° Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 8/15/2017 OIL ❑ WINJ ❑ WDSPL El Suspended ❑ 16.Verbal Approval: Date: GAS El. WAG ❑ GSTOR ❑ SPLUG 0 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. Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarloweU@hllcorp.com Contact Phone:X907)283-1329 Authorized Signature: 1.0,,.,.c0'.�L. rL., Date: 1/7.5 )1"'1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number L, _ 4114 Plug Integrity IDBOP Test❑ Mechanical Integrity Test LI Location Clearance Other: Post Initial Injection MIT Req'd? Yes 0 No ❑ RBDMS (L AUG - 9 2017 Spacing Exception Required? Yes ❑ No In Subsequent Form Required: /0„... V y APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: e i 1 1,1 ` ` (t n G IN A L ��_ / Submit Form and (J �\ Form 10-403 Revis€d 4/2017 �Ap r vd application is valid for 12 months fromthe date of approval.„ Attachments in Duplicate • • • Well Work Prognosis Well: M-17 HiIearp Alaska,Li.c Date: 07/24/17 Well Name: Trading Bay Unit M-17 API Number: 50-733-20552-00 Current Status: Gas Well Leg: A-1 (West) Estimated Start Date: 08/15/2017 Rig: E-Line Reg.Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 207-120 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Second Call Engineer: Stan Golis Office: 907-777-8356 Current Bottom Hole Pressure: 615 psi @ 2,823'TVD 0.218 psi/ft SIBP Maximum Expected BHP: 1,100 psi @ 2,613'TVD 0.421 psi/ft high case for new perfs Maximum Potential Surface Pressure: 839 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) **well to be perforated well flowing Last Casing Test: 11/19/2015 1,500 psig at 1,390'for 30 minutes on chart Brief Well Summary: Well M-17 is a gas well completed in the A Sands.This project will add perforations in the SZ-23. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line guns and perforate with well flowing per program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic • • McArthur River Field 111 SCHEMATIC Steelhead Platform Well M-17 Hamra Alaska,LLC Cornpleted: 11/22/2015 CASING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM(MDrkb) 28" Structural 27 Surface 485' RKB to TBG Head 71.82' 13-3/8" 68 L-80 BTC 12.415 Surface 895' 9-5/8" 40 L-80 BTC 8.835 Surface 1,430' I. i `@ 7" 26 L-80 BTC-M 6.276 Surface 5,700' k 28"Conductor 5"liner 18 L-80 H513 4.180" 5,472' 7,637' ECP Stage Collar TUBING DETAIL SA 13-3/g"in 17.4 Hole 3-1/2" 9,2 L-80 TC-II 2.992 Surf 1,415' 4� ECP Stage Collar 3-1/2" 9.2 L-80 TC-II 2.992 4,975' 5,098' TOC @ 1,053' °The 5",189,FJ liner has an ID of 4.276"&drift of 4.155". The H513 connection has a 4.194"machined pin ID.The Baker ZXP Flex III hanger packer assembly has a TKC x H513 X over with a 4.180"machined ID.This represents the minimum ID in the 5"liner. Top Fish:Debris from 5"drillable bridge plugs. Bottom Fish: 2.5X15'Spiral Jet EJ gun,1-11/16"x 1.5 firing head,1-11/16"x 1.5'magnet,1-11/16"x 1'CCL,1-11/16"x 1'swivel,1-11/16" x 18'weight bar,1-3/8"x 22'rope socket. L 2 '' 9-5/8"in 12 i" Jewelry Detail 3 Hole No. Item Depth(MD) Depth(TVD) OD ID Notes 13 3/8 x 28"ECP Stage Collar 454' 454' Cemt'd to Surf 4 N: 9 5/8 x 13 3/8 ECP Stage Collar 849' 849' Attempt to Cemt to ML '- S 1 SSSV 414' 414' 5.375" 2.813" 2 GLM 1,362' 1,343' 5.00" 2.813" A Zone 3 AS1-X Retrievable Packer 1,390' 1,368' 5.870" 3.00" 4 X-Nipple 1,406' 1,382' 4.50" 2.813" B&C Zone 5 WLEG 1,415' 1,390' 4.50" 2.992" I_ Top of tubing 6 Production Packer 4,980' 4,044' 5.97" 3.900" Baker S-3 'r` @ 4 975, 7 X Profile Nipple w/X-Plug 5,040' 4,096' 4.50" 2.813" 68 WLEG(bottom) 5,098' 4,146' 3.93" 2.960" 7 - 9 ZXP Flex III Hanger Packer 5,472' 4,471' 5.250" 4.180" i' - 10 5"Cement Retainer 7,213' 5,980' >>» »» Top of Cement at 7,200' 8 C5 Zone TOC 5,276 - C7 Zone r m Perforation Detail " MD ND Date Zone (SPF) Notes a 'r- 3,535'-3,550' 2,823'-2,833' 10/29/16 A-3 6 3,577'-3,592' 2,853'-2,865' 12/17/15 A-3 3,981-3,9883,179-3,1851216 "a■ 7"Casing in 814" ' ' ' ' / /15 A-6 4,440'-4,447' 3,576'-3,582' 12/7/16 B-3 5 Open 4,454'-4,480' 3,589'-3,611' 12/7/16 13-3 5 Open I D3B Zone(sqzd plugged) t„�; 4,844'-4,860' 3,926'-3,940' 12/6/16 C-1 5 Open u1p 5,147'-5,167' 4,189'-4,206' 6/18/2012 C-5 6 Isolated toy; 5,229'-5,236' 4,260'4,226' 6/15/2012 C-7 4 Isolated fit, 5,782'-5,788' 4,740'-4,745' 11/29/2007 6 Squeezed,Ref SCMT Log 11/22/07 5,832'-5,856' 4,784'-4,805' 2/19/2008 D-3B 5 Squeezed,112.5 bbls 15.8 ppg LXT 6,029'-6,042' 4,955'-4,967' 6/1/2012 D-4 4 2-1/2"Shogun Strip 60 deg Spiral Strip D4 Zone 6,066'-6,073' 4,988-4,994' 6/1/2012 D-4 4 2-1/2"Shogun Strip 60 deg Spiral Strip D4 Zone 6,169'-6,179' 5,078'-5,086' 6/1/2012 D-6 4 2-1/2"Shogun Strip 60 deg Spiral Strip Top of D6 zone 6,234'-6,240' 5,135'-5,140' 11/27/2007 6 Squeezed,Ref SCMT Log 11/22/07 Primary 7,142'-7,155' 5,919'-5,930' 4/5/2010 D-14 6 SLB 2-1/2"PJ Omega HC 60°phasing Cement #-, 7,296'-7,308' 6,052'-6,062' 2/16/2008 D-16A 6-11 Plugged/Squeezed thru cement retainer at 7213'with is 7034' w 3.25 bbls of LXT cement and 2 bbls dumped on top and D14 Zone 7,361'-7,391' 6,108'-6,135' 2/13/2008 D-16C 6-11 4 dressed to 7200' to = 7200 Top of Cement Plug at Isolated with 5"Posi-Set Plug at 7423'and 15.25 gals ' * i D16A Zone(sgzd plugged) 7,456'-7,470' 6,191'-6,204' 12/21/2008 D-17 11 (18')of dump bailed cement. ..,k .sem. D16C Zone(said olueeedl s "ni D17 Zone(plugged) A k"" 5"Posi-Set plug at 7423'w/15.23 gals cmt placed w/dump bailer(TOC Note:Placed 2'of ceramic beads on top of sand fill @ 5"Liner Shoe at 7637' tagged at 7405'ELM,2-11-081 6-1/8"Hole TD at 7670' 5,297'• MAX HOLE ANGLE: 56.4°@ Tangent 2,796' MD Revised: 12/22/16 byJLL • • McArthur River Field II PROPOSED Steelhead Platform Well M-17 Hilcorp Alaska,LLC Completed: 11/22/2015 CASING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM(MDrkb) 28" Structural 27 Surface 485' RKB to TBG Head 71.82' 13-3/8" 68 L-80 BTC 12.415 Surface 895' 9-5/8" 40 L-80 BTC 8.835 Surface 1,430' 7" 26 L-80 BTC-M 6.276 Surface 5,700' I 28"Conductor 5"liner 18 L-80 H513 4.180* 5472' 7,637' A ECP Stage Collar TUBING DETAIL 13-3/8"in 17'A"Hole 3-1/2" 9.2 L-80 TC-II 2.992 Surf 1,415' ECP Stage Collar 3-1/2" 9.2 L-80 TC-II 2.992 4,975' 5,098' i °The 5",180,FJ liner has an ID of 4.276"&drift of 4.155". The H513 connection has a 4.194"machined pin ID.The Baker ZXP Flex III TOC @ 1,053' hanger packer assembly has a TKC x H513 X over with a 4.180"machined ID.This represents the minimum ID in the 5"liner. Top Fish:Debris from 5"drillable bridge plugs. Bottom Fish: 2.5X15'Spiral Jet EJ gun,1-11/16"x 1.5 firing head,1-11/16"x 1.5'magnet,1-11/16"x 1'CCL,1-11/16"x 1'swivel,1-11/16" x 18'weight bar,1-3/8"x 22'rope socket. L 2 1 IN 1. 9-5/8"in 12'A" 3rr Hole Jewelry Detail No. Depth(MD) Depth(TVD) OD ID Item Notes 4 l !{ 454' 454' 13 3/8 x 28"ECP Stage Collar Cemt'd to Surf 5 1' SZ Zone 849' 849' 9 5/8 x 13 3/8 ECP Stage Collar Attempt to Cemt to ML A Zone 1 414' 414' 5.375" 2.813" SSSV B&C Zone 2 1,362' 1,362' 5.00" 2.813" GLM g _ Top of tubing 3 1,390' 1,390' 5.870" 3.00" AS1-X Retrievable Packer 6 @ 4,975' 4 1,406' 1,406' 4.50" 2.813" X-Nipple 7L 5 1,415' 1,415' 4.50" 2.992" WLEG 8 CS Zone 6 4,980' 4,980' 5.97" 3.900" Production Packer Baker 5-3 TCC 5,27G C7 Zone 7 5,040' 5,040' 4.50" 2.813" X Profile Nipple w/X-Plug 8 5,098' 5,098' 3.93" 2.960" WLEG(bottom) 9 5,472' 5,472' 5.250" 4.180" ZXP Flex III Hanger Packer 10 7,213' 7,213' »» »» 5"Cement Retainer Top of Cement at 7,200' L.] 9 ,,:,,,,___6, 7"Casing in S i4" `.' D3B Zone(sqzd plugged) Perforation Detail MD TVD Date Zone (SPF) Notes ±3,216'-±3,232' ±2,613'-±2,623' FUTURE SZ-23 6 PROPOSED 3,535'-3,550' 2,823'-2,833' 10/29/2016 A-3 6 D4 Zone 3,577'-3,592' 2,853'-2,865' 12/17/2015 A-3 6 3,981'-3,988' 3,179'-3,185' 12/16/2015 A-6 6 D4 Zone 4,440'-4,447' 3,576'-3,582' 12/07/2016 8-3 5 Open Top of D6 Zone 4,454'-4,480' 3,589'-3,611' 12/07/2016 B-3 5 Open Primary Cement 4,844'-4,860' 3,926'-3,940' 12/06/2016 C-1 5 Open is 7034' D14Zone 5,147'-5,167' 4,189'-4,206' 06/18/2012 C-5 6 Isolated 5,229'-5,236' 4,260'-4,226' 06/15/2012 C-7 4 Isolated 10 J� Top of Cement Plug at 5,782'-5,788' 4,740'-4,745' 11/29/2007 N/A 6 Squeezed,Ref SCMT Log 11/22/07 D16A Zone(sqzd plugged) 5,832'-5,856' 4,784'-4,805' 02/19/2008 D-3B 5 Squeezed,112.5 bbls 15.8 ppg LXT D16C Zone(sgzd olueeedl 6,029'-6,042' 4,955'-4,967' 06/01/2012 D-4 4 2-1/2"Shogun Strip 60 deg Spiral Strip t 6,066'-6,073' 4,988'-4,994' 06/01/2012 D-4 4 2-1/2"Shogun Strip 60 deg Spiral Strip 'Ak 017 Zone(plugged) 6,169'-6,179' 5,078'-5,086' 06/01/2012 D-6 4 2-1/2"Shogun Strip 60 deg Spiral Strip IIMit' 6,234'-6,240' 5,135'-5,140' 11/27/2007 N/A 6 Squeezed,Ref SCMT Log 11/22/07 5"Posi-Set plug at 7423'w/15.23 5"Liner Shoe at 7637' gals cmt placed w/dump bailer 7,142'-7,155' 5,919'-5,930' 04/05/2010 D-14 6 SW 2-1/2"PJ Omega HC 60°phasing 6-1/8"Hole TD at 7670' (TOC tagged at 7405'ELM,2-11-08) 7,296'-7,308' 6,052'-6,062' 02/16/2008 D-16A 6-11 Plugged/Squeezed thru cement retainer at 7213'with 7,361'-7,391' 6,108'-6,135' 02/13/2008 D-16C 6-11 3.25 bbls of LXT cement and 2 bbls dumped on top and MAX HOLE ANGLE: dressed to 7200' 7,456'-7,470' 6,191'-6,204' 12 21 2008 D-17 11 Isolated with 5"Posi-Set Plug at 7423'and 15.25 gals 56.4 @ Tangent 2,796' MD / / (18')of dump bailed cement. Note:Placed 2'of ceramic beads on top of sand fill @ 5,297'. Revised:07/24/17 by JLL • • Bettis, Patricia K (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Wednesday,July 26, 2017 1:05 PM To: Bettis, Patricia K(DOA) Subject: RE:TBU M-17 (PTD 207-120): Sundry Application Yes, It is the Middle Kenai Gas Pool From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Wednesday,July 26, 2017 10:46 AM To: Dan Marlowe<dmarlowe@hilcorp.com> Subject:TBU M-17 (PTD 207-120): Sundry Application Good morning Dan, Is the SZ-23 zone still within the Middle Kenai Gas Pool or is it in another pool? Please advise. If SZ-23 is in another pool, please identify. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Wednesday,July 26, 2017 10:46 AM To: dmarlowe@hilcorp.com Subject: TBU M-17 (PTD 207-120): Sundry Application Good morning Dan, Is the SZ-23 zone still within the Middle Kenai Gas Pool or is it in another pool? Please advise. If SZ-23 is in another pool, please identify. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 Anchorage,AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@ialaska.gov. 1 STATE OF V A OIL AND GAS CONSERVATION COMAION 00 REPORT OF SUNDRY WELL OPERATIONS 810/ 94 13a 1.Operations Abandon El Plug Perforations❑ Fracture Stimulate El Pull Tubing El i .41- Performed: rtPerformed: Suspend ❑ Perforate l' Other Stimulate ❑ Alter Casing❑ tgarq`Ar3plomgdPo. . tt Plug for Redrill Cl Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well 0 Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 2 Exploratory❑ 207-120 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20552-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017594/ADL0018730 Trading Bay Unit M-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Middle Kenai Gas Pool 11.Present Well Condition Summary: Total Depth measured 7,670 feet Plugs measured 5,040 feet true vertical 6,380 feet Junk measured N/A feet Effective Depth measured 5,040 feet Packer measured 1,390,4,980,5,472 feet true vertical 4,096 feet true vertical 1,368,4,044,4,471 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 485' 28" 485' 484' Surface 895' 13-3/8" 895' 894' 5,020 psi 2,260 psi Intermediate 1,430' 9-5/8" 1,430' 1,403' 5,750 psi 3,090 psi Production 5,700' 7" 5,700' 4,669' 7,240 psi 5,410 psi Liner 2,165' 5" 7,637' 6,350' 8,290 psi 7,250 psi Perforation depth Measured depth 3,535-4,860 feet True Vertical depth 2,823-3,940 feet 3-1/2" 9.2#/L-80 1,415'(MD) 1,390'(MD) Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 5,098'(MD) 4,146'(TVD) AS1-X Ret.Pkr 1,390'(MD)1,368'(TVD) Packers and SSSV(type,measured and true vertical depth) Prod.Pkr 4,980'(MD)4,044'(TVD)3-1/2"EUE 8rd SSSV 414'(MD)414'(TVD) ZXP Flex III Hgr Pkr 5,472'(MD)4,471'(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N7 t t� N/A SCANNED 1,, I2. 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 1560 0 68 43 Subsequent to operation: 0 1410 0 50 40 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory❑ Development Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas 2 WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ ❑ WAG ❑ GINJ 0 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: 316-596 Contact Dan Marlowe(907)283-1329 , Email dmarlowe(c hilcorq.com Printed Name Stan W.Golis GG ,,,,,,,t,, 06.A Title Operations Manager .J Signature tt..,. 0 Phone (907)777-8356 Date %/'/'*.`l /I' !Z„���-i6 K I RBDMS U" DEC 2 8 2016 Form 10-404 Revised 5/2015 ORI R 1 , i" d , Submit Original Only McArthur River Field II 40 SCHEMATIC • Steelhead Platform Well M-17 Hilcorp Alaska,LLC Completed: 11/22/2015 CASING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM(MDrkb) 28" Structural 27 Surface 485' RKB to TBG Head 71.82' 13-3/8" 68 L-80 BTC 12.415 Surface 895' 9-5/8" 40 L-80 BTC 8.835 Surface 1,430' 7" 26 L-80 BTC-M 6.276 Surface 5,700' 1 28"Conductor 5"liner 18 L-80 H513 4.180* 5472' 7,637' ECP Stage Collar TUBING DETAIL 3-1/2" 9.2 L-80 TC-II 2.992 Surf 1,415' A 13-3/8"in 17'h"Hole ECP Stage Collar 3-1/2" 9.2 1-80 TC-II 2.992 4,975' 5,098' Est TOC @ 920' 'The 5",188,FJ liner has an ID of 4.276"&a drift of 4.155". The H513 connection has a 4.194"machined pin ID.The Baker ZXP Flex III hanger packer assembly has a TKC x H513 X over with a 4.180"machined ID.This represents the minimum ID in the 5"liner. Top Fish:Debris from 5"drillable bridge plugs. Bottom Fish: 2.5X15'Spiral Jet EJ gun,1-11/16"x 1.5 firing head,1-11/16"x 1.5'magnet,1-11/16"x 1'CCL,1-11/16"x 1'swivel,1-11/16" x 18'weight bar,1-3/8"x 22'rope socket. MB 4, 2 ••• 9-5/8"in 12/,"Hole Jewelry Detail 3 No. Item Depth OD ID Notes 13 3/8 x 28"ECP Stage Collar 454' Cemt'd to Surf 4 9 5/8 x 13 3/8 ECP Stage Collar 849' Attempt to Cemt to ML 1 SSSV 414' 5.375" 2.813" 5 2 GLM 1,362' 5.00" 2.813" A Zone 3 AS1-X Retrievable Packer 1,390' 5.870" 3.00" - "", 4 X-Nipple 1,406' 4.50" 2.813" B&C Zone 5 WLEG 1,415' 4.50" 2.992" ,r z= Top of tubing 6 Production Packer 4,980' 5.97" 3.900" Baker S-3 6 I I I " I @ 4,975' 7 X Profile Nipple w/X-Plug 5,040' 4.50" 2.813" - 8 WLEG(bottom) 5,098' 3.93" 2.960" 7 9 ZXP Flex III Hanger Packer 5,472' 5.250" 4.180" 10 5"Cement Retainer 7,213' >>» »» Top of Cement at 7,200' 8 C5 Zone TOC 5 276 C7 Zone Perforation Detail MD TVD Date Zone (SPF) Notes 3,535'-3,550' 2,823'-2,833' 10/29/16 A-3 6 3,577'-3,592' 2,853'-2,865' 12/17/15 A 3 9 3,981'-3,988' 3,179'-3,185' 12 16/15 A 6 7"Casing in 8;4"Hole� / 4,440'-4,447' 3,576'-3,582' 12/7/16 B-3 5 Open l/ 4,454'-4,480' 3,589'-3,611' 12/7/16 8-3 5 Open / D3B Zone(sqzd plugged) ,p/ 4,844'-4,860' 3,926'-3,940' 12/6/16 C-1 5 Open :-/- .z 5,147'-5,167' 4,189'-4,206' 6/18/2012 C5 6 Isolated ll "4 5,229'-5,236' 4,260'-4,226' 6/15/2012 C7 4 Isolated 5,782'-5,788' 4,740'-4,745' 11/29/2007 6 Squeezed,Ref SCMT Log 11/22/07 5,832'-5,856' 4,784'-4,805' 2/19/2008 D3B 5 Squeezed,112.5 bbls 15.8 ppg LXT v r 6,029'-6,042' 4,955'-4,967' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip k°4� D4 Zone 6,066'-6,073' 4,988-4,994' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip * "5 -J D4 Zone 6,169'-6,179' 5,078'-5,086' 6/1/2012 D6 4 2-1/2"Shogun Strip 60 deg Spiral Strip Top of 14 { D6 Zone 6,234'-6,240' 5,135'-5,140' 11/27/2007 6 Squeezed,Ref SCMT Log 11/22/07 Primary s. k: :pr 7,142'-7,155' 5,919'-5,930' 4/5/2010 D14 6 SLB 2-1/2"PJ Omega HC 60°phasing Cement r". ' e 7,296'-7,308' 6,052'-6,062' 2/16/2008 D-16A 2-Sep Plugged/Squeezed thru cement retainer at 7213' is 7034' a,x', ���+��+�.�:, 014 Zone 7,361'-7,391' 6,108'-6,135' 2/13/2008 0-16C 2-Sep with 3.25 bbls of LXT cement and 2 bbls dumped on IIIIII__ top and dressed to 7200' 1�� Top of Cement Plug at 7200' Isolated with 5"Posi-Set Plug at 7423'and 15.25 l0 7,456'-7,470' 6,191'-6,204' 12/21/2008 D-17 11 D16A Zone(sqzd plugged) gals(18')of dump bailed cement. sem, D16C Zone Is°zd olueeedl r _:2. D17 Zone(plugged) al 5"Posi-Set plug at 7423'w/15.23 gals cmt placed w/dump bailer(TOC 5"Liner Shoe at 7637' tagged at 7405'ELM,2-11-08) 6-1/8"Hole TD at 7670' MAX HOLE ANGLE: 56.4°@ Tangent 2,796'MD Note:Placed 2'of ceramic beads on top of sand fill @ 5,297'. Revised: 12/22/16 by JLL Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date M-17 Eline 50-733-20552-00 207-120 12/6/16 12/7/16 Daily Operations: 12/06/16-Tuesday Mobilized crew to Steelhead & orientated. PJSM. Unloaded boat. R/u e-line tools ( 16' 2 3/8" 5 spf, 60 deg phasing, loaded w/Geo Razor 11 gm charges) gr/ccl. PT lubricator 250/ 1500 psi,good. Rih t/4950' wlm, log up t/4700', correlate to existing log, send log to Res Eng.Verify good. Fire guns w/top shot @ 4844, btm rvshot4860',good indication at surface guns fired, no change in tp or flow when shot. POOH. Production cont. flow well w/no change. Load 26' 2 3/8" 5 spf, 60 deg phasing, guns w/Geo Razor 11 gm charges. M/u gr/ccl, pres/temp tools. Rih t/200', line fouled on drum, straighten out line, POOH. L/d tools/guns. Stripped line from drum, re-head. L/d crew. 12/07/16/16-Wednesday PJSM. P/U e-line tools ( 26' 2 3/8" 5 spf, 60 deg phasing, loaded w/Geo Razor 11 gm charges)gr/ccl, temp/press. Rih t/4950' correlate t/ex log.Verify w/ res eng. - good (found fluid level @4720'. Platform went black, stand by while production comes back online and well is stabilized. Shoot guns w/top shot @ 4454', btm @ 4480'good indication at surface guns fired. P/u & monitor well. POOH. L/d spent guns, all shots fired. P/U e-line tools ( 7' 2 3/8" 5 spf, 60 deg phasing, loaded w/Geo Razor 11 gm charges)gr/ccl, temp/press. Rih t/4950' correlate t/ex log, verify w/ res eng. good. Shoot guns w/top shot @ 4. 440', btm @ 4447'good indication at surface guns fired. Log P/T f/3400't/4930', found fluid level @ 3810'. POOH. R/D e-line, replace hatch cover. • of t • • y \1 1//7_ s� THE STATE Alaska Oil and Gas ofLAS]` -1 � �, Conservation Commission A 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OAMain: 907.279.1433 A_AS' Fax: 907.276.7542 I W. Golis www.aogcc.alaska.gov Operations ManagerFEE 27 Ep 2C l, Hilcorp Alaska, LLC SCANN 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: McArthur River Field,Middle Kenai Gas Pool,TBU M-17 Permit to Drill Number: 207-120 Sundry Number: 316-596 Dear Mr. Golis: 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 P. oerster Chair DATED this�day of November,2016. RBD6VIS feu r t. 8 2015 • • RECEIVED • STATE OF ALASKA NOV 18 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ' GC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ 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 ❑ • 207-120 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service El 6.API Number. Anchorage,AK 99503 50-733-20552-00 . 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A • Will planned perforations require a spacing exception? Yes ❑ No 0 ✓ Trading Bay Unit M-17 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594/ADL0018730 ' McArthur River Field/Middle Kenai Gas Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 7,670 . . 6,380 • 5,040 . 4,096 858 psi 5,040 N/A Casing Length Size MD ND Burst Collapse Structural Conductor 485' 28" 485' 484' Surface 895' 13-3/8" 895' 894' 5,020 psi 2,260 psi Intermediate 1,430' 9-5/8" 1,430' 1,403' 5,750 psi 3,090 psi Production 5,700' 7" 5,700' 4,669' 7,240 psi 5,410 psi Liner 2,165' 5" 7,637' 6,350' 8,290 psi 7,250 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 3,535-3,988 • 2,823-3,185 3-1/2" 9.2#/L-80 1,415'&5,098' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): r AS1-X Ret Pkr/Baker S-3/ZXP Flex III Hanger Packer& SSSV 1,390'(MD)1,368'(TVD)4,980'(MD)4,044'(TVD)/5,472'(MD)4,471'(TVD)&414' (MD)414'(ND) 12.Attachments: Proposal Summary E Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development • Service 0 14.Estimated Date for 15.Well Status after proposed work: 12/5/2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS O• WAG ❑ 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 Dan Marlowe(907)283-1329 Email dmarloweehilcorp.com Printed Name Stan W. G+olis` Title Operations Manager Signature StanW.Golis� Phone (907)777-8356 Date s / i '' I t iO COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ;c2" t i 1.14... ' Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /Q.-cI 0 c.I ��® � �✓ �o 3 APPROVED BY NOVIv / Approved by: COMMISSIONER THE COMMISSION Date: Il- .2 2--4. IN"'el„. 911,471.4.-- ) NAL Ai (% 4•A S1/-1/"/6 Submit Form and Form 10-403 Revised 11/2015 ORiep�IiCatioh is valid for 12 months from the date of approval. Attachments in Duplicate • Well Work Prognosis Well: M-17 Hilcorp Alaska.1.r r; Date: 11/16/16 Well Name: Trading Bay Unit M-17 API Number: 50-733-20552-00 Current Status: Gas Well Leg: A-1 (West) Estimated Start Date: 12/05/2016 Rig: E-Line Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 207-120 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell:907-398-9904 Second Call Engineer: Stan Golis Office: 907-777-8356 Current Bottom Hole Pressure: 615 psi @ 2,823'TVD 0.218 psi/ft SIBP Maximum Expected BHP: 1,140 psi @ 2,823'TVD 0.404 psi/ft high case for new perfs Maximum Potential Surface Pressure: 858 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) **Well to be perforated while flowing Last Casing Test: 11/19/2015 1,500 psig at 1,390' for 30 minutes on chart Brief Well Summary: Well M-17 is a gas well completed in the A Sands.This project will add new perforations in the B-3 &C-1 sands. 7 E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line guns and perforate with well flowing in the following order. a. Shoot upper C-1 sand ±4,844'-±4,860' and flow test b. If Upper C-1 is productive shoot Lower C-1 sand ±4,869'-±4,892' and flow test c. If either C-1 sand was wet, set a plug and cement at±4,840' d. Shoot Lower B-3 sand ±4,454'-±4,480',then upper B-3 sand ±4,440'-±4,447'and flow test e. If B-3 sand is wet set a plug and cement at±4,435' 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic River Field SSCHEMATIC • McArthurSteelhead Rivtform Well M-17 • liilcorp Alaska,LLC Completed: 11/22/2015 CASING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM(MDrkb) 28" Structural 27 Surface 485' RKB to TBG Head 71.82' 13-3/8" 68 L-80 BTC 12.415 Surface 895' 9-5/8" 40 L-80 BTC 8.835 Surface 1,430' 7"1 26 L-80 BTC-M 6.276 Surface 5,700' 28"Conductor 5"liner 18 L-80 H513 4.180` 5472' 7,637' ECP Stage Collar TUBING DETAIL A13-3/8"in 1714"Hole 3-1/2" 9.2 L-80 TC-II 2.992 Surf 1,415' ECP Stage Collar 3-1/2" 9.2 L-80 TC-II 2.992 4,975' 5,098' Est TOC @ 920' `The 5",188,Fl liner has an ID of 4.276"&a drift of 4.155". The H513 connection has a 4.194"machined pin ID.The Baker ZXP Flex III hanger packer assembly has a TKC x H513 X over with a 4.180"machined ID.This represents the minimum ID in the 5"liner. Top Fish:Debris from 5"drillable bridge plugs. Bottom Fish: 2.5X15'Spiral Jet EJ gun,1-11/16"x 1.5 firing head,1-11/16"x 1.5'magnet,1-11/16"x 1'CCL,1-11/16"x 1'swivel,1-11/16" x 18'weight bar,1-3/8"x 22'rope socket. 1 2iii A 9-5/8"in 12 G"Hole Jewelry Detail 3 No. Item Depth OD _ ID Notes 13 3/S x 28"ECP Stage Collar 454' Cemt'd to Surf 4 X 9 5/8 x 13 3/8 ECP Stage Collar 849' Attempt to Cemt to ML 1 SSSV 414' 5.375" 2.813" 5 2 GLM 1,362' 5.00" 2.813" 3 AS1-X Retrievable Packer 1,390' 5.870" 3.00" AZone 4 X-Nipple 1,406' 4.50" 2.813" 5 WLEG 1,415' 4.50" 2.992" 4 Top of tubing 6 Production Packer 4,980' 5.97" 3.900" Baker S-3 I I @ 4,975' 7 X Profile Nipple w/X-Plug 5,040' 4.50" 2.813" 6 -1*-' 8 WLEG(bottom) 5,098' 3.93" 2.960" 7 9 ZXP Flex III Hanger Packer 5,472' 5.250" 4.180" 10 5"Cement Retainer 7,213' >>» »» Top of Cement at 7,200' 8 = C5 Zone TOC 5,276 = C7 Zone Perforation Detail MD TVD Date Zone (SPF) Notes i.,' '' 3,535'-3,550' 2,823'-2,833' 10/29/16 A-3 6 4,i,-:' 3,577-3,592' 2,853'-2,865' 12/17/15 A 3 9 %f '1 7"Casing in 8'r4"Hole 3,981'-3,988' 3,179'-3,185' 12/16/15 A 6 5,147'-5,167' 4,189'-4,206' 6/18/2012 C5 6 Isolated • 5,229'-5,236' 4,260'-4,226' 6/15/2012 C7 4 Isolated 1:.r D3B Zone(sqzd plugged) 5,782'-5,788' 4,740'-4,745' 11/29/2007 6 Squeezed,Ref SCMT Log 11/22/07 5,832'-5,856' 4,784'-4,805' 2/19/2008 D3B 5 Squeezed,112.5 bbls 15.8 ppg LXT 6,029'-6,042' 4,955'-4,967' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip - 4 6,066'-6,073' 4,988-4,994' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip 6,169'-6,179' 5,078'-5,086' 6/1/2012 D6 4 2-1/2"Shogun Strip 60 deg Spiral Strip 6,234'-6,240' 5,135'-5,140' 11/27/2007 6 Squeezed,Ref SCMT Log 11/22/07 D42one 7,142'-7,155' 5,919'-5,930' 4/5/2010 D14 6 SLB 2-1/2"PJ Omega HC 60°phasing D4 Zone 7,296'-7,308' 6,052'-6,062' 2/16/2008 D-16A 2-Sep Plugged/Squeezed thru cement retainer at 7213' with 3.25 bbls of LXT cement and 2 bbls dumped on Top of `= D6 Zone 7,361'-7,391' 6,108'-6,135' 2/13/2008 D-16C 2-Sep top and dressed to 7200' Primary Cement7,456'-7,470' 6,191'-6,204' 12/21/2008 D-17 11 Isolated with 5"Posi-Set Plug at 7423'and 15.25 is 7034' gals(18')of dump bailed cement. D14 Zone Top of Cement Plug at 7200' Ill 016A Zone(sqzd plugged) 016C Zone Isozd olueeed) rD17 Zone(plugged) iii5"Posi-Set plug at 7423'w/15.23 gals vest placed w/dump bailer(TOC 5"Liner Shoe at 7637' tagged at 7405'ELM,2-31-081 6-1/8"Hole TD at 7670' MAX HOLE ANGLE: 56.4°@ Tangent 2,796'MD Note:Placed 2'of ceramic beads on top of sand fill @ 5,297'. Revised: 11/16/16 by JLL McArthur River Field n • PROPOSED • Steelhead Platform Well M-17 Hilcorp Alaska,LLC Completed: 11/22/2015 CASING DETAIL SIZE WT _ GRADE CONN MIN ID TOP BTM(MDrkb) 28" _ Structural 27 Surface 485' RKB to TBG Head 71.82' 13-3/8" _ 68 L-80 BTC 12.415 Surface 895' 9-5/8" 40 L-80 BTC 8.835 Surface 1,430' 7„1 1.11 26 L-80 BTC-M 6.276 Surface 5,700' 28"Conductor 5"liner 18 L-80 H513 4.180• 5472' 7,637' ECP Stage Collar TUBING DETAIL CI 13-3/8"in 17'A"Hole 3-1/2" 9.2 L-80 TC-II 2.992 Surf 1,415' ECP Stage Collar 3-1/2" 9.2 L-80 TC-II 2.992 4,975' 5,098' Est TOC @ 920' 'The 5",188,F1 liner has an ID of 4.276"&a drift of 4.155". The H513 connection has a 4.194"machined pin ID.The Baker ZXP Flex III hanger packer assembly has a TKC x H513 X over with a 4.180"machined ID.This represents the minimum ID in the 5"liner. Top Fish:Debris from 5"drillable bridge plugs. Bottom Fish: 2.5X15'Spiral let El gun,1-11/16"x 1.5 firing head,1-11/16"x 1.5'magnet,1-11/16"x 1'CCL,1-11/16"x 1'swivel,1-11/16" x 18'weight bar,1-3/8"x 22'rope socket. L 2 , 9-5/8"in 12''4"Hole Jewelry Detail 3 _ ' I No. Item Depth OD ID Notes di LB- 13 3/8 x 28"ECP Stage Collar 454' Cemt'd to Surf A 9 5/8 x 13 3/8 ECP Stage Collar 849' Attempt to Cemt to ML 1 SSSV 414' 5.375" 2.813" 5 2 GLM 1,362' 5.00" 2.813" A Zone 3 AS1-X Retrievable Packer 1,390' 5.870" 3.00" 4 X-Nipple 1,406' 4.50" 2.813" - B&C Zone 5 WLEG 1,415' 4.50" 2.992" 6 Production Packer 4,980' 5.97" 3.900" Baker S-3 I__`- Top of tubing 1 -(,1 gy. 1 7 X Profile Nipple w/X-Plug 5,040' 4.50" 2.813" 6 _ @ 4,975' . 8 WLEG(bottom) 5,098' 3.93" 2.960" 7iir. 9 ZXP Flex III Hanger Packer 5,472' 5.250" 4.180" 10 5"Cement Retainer 7,213' »» »» Top of Cement at 7,200' 8 - C5 Zone TOC 5 276 - C7 Zone Perforation Detail *'a MD ND Date Zone (SPF) Notes ajr' "ffiwp 3,535'-3,550' 2,823'-2,833' 10/29/16 A-3 6 3,577'-3,592' 2,853'-2,865' 12/17/15 A 3 9 0 ^ 3,981'-3,988' 3,179'-3,185' 12/16/15 A 6 7"Casing in 8''A"Hole ,Ir't :a• ±4,440'-±4,447' ±3,576'-±3,582' Future B-3 Proposed iS,' ±4,454'-±4,480' ±3,589'-±3,611' Future B-3 Proposed w' , D3B Zone(sqzd plugged) ±4,844'-±4,860' ±3,926'-±3,940' Future C-1 Proposed *•' °`^J ±4,869'-±4,892' ±3,948'-±3,968' Future C-1 Proposed fi 5,147'-5,167' 4,189'4,206' 6/18/2012 C5 6 Isolated i' ' 1, ` a✓ t 5,229'-5,236' 4,260'-4,226' 6/15/2012 C7 4 Isolated 4, *r°"" 5,782'-5,788' 4,740'-4,745' 11/29/2007 6 Squeezed,Ref SCMT Log 11/22/07 pra C. 5,832'-5,856' 4,784'-4,805' 2/19/2008 D3B 5 Squeezed,112.5 bbls 15.8 ppg LXT li4,. { D4 Zone 6,029'-6,042' 4,955'4,967' 6/1/2012 04 4 2-1/2"Shogun Strip 60 deg Spiral Strip :'?1a"`"a r D4 Zone 6,066'-6,073' 4,988-4,994' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip Top of Tr :d, D6 Zone 6,169'-6,179' 5,078'-5,086' 6/1/2012 D6 4 2-1/2"Shogun Strip 60 deg Spiral Strip � Primary '"it...'-t . 6,234'-6,240' 5,135'-5,140' 11/27/2007 6 Squeezed,Ref SCMT Log 11/22/07 Cement7,142'-7,155' 5,919'-5,930' 4/5/2010 014 6 SLB 2-1/2"PJ Omega HC 60°phasing is 7034' :' 014 Zone 7,296'-7,308' 6,052'-6,062' 2/16/2008 0-16A 2-Sep Plugged/Squeezed thru cement retainer at 7213' 'ill:',,,', r, with 3.25 bbls of LXT cement and 2 bbls dumped on Top of Cement Plug at 7200' 7.361'-7,391' 6,108'-6,135' 2/13/2008 D-16C 2-Sep top and dressed to 7200' 10 (sgzd plugge7, 6'-7, , 1'-6, Isolated with 5"Posi-Set Plug at 7423'and 15.25 z D16CD16A zoneZone Isozd olaeeedld) 7,456-7,470' 6,19r-6,204' 12/21/2008 D-17 11 gals(18')of dump bailed cement. eD17 Zone(plugged) 4 , s"Pod-Set plug at 7423'w/15.23 gals cmt placed w/dump bailer(TOC 5"Liner Shoe at 7637' tagged at 7405'ELM,2-11-081 6-1/8"Hole TD at 7670' MAX HOLE ANGLE: 56.4°@ Tangent 2,796'MD Note:Placed 2'of ceramic beads on top of sand fill @ 5,297'. Revised: 11/18/16 by JLL STATE OF ALASKA AI&OIL AND GAS CONSERVATION COMAION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon El Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Other: 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 207-120 3,Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20552-00 ( 7.Property Designation(Lease Number): 8.Well Name and Number: M ADL0017594/ADL0018730 Trading Bay Unit M-17 § 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): �' a !0 N/A McArthur River Field/Middle Kenai Gas Pool ,�`'� 11.Present Well Condition Summary: A.0(.,:`,0G Total Depth measured 7,670 feet Plugs measured 5,040 feet true vertical 6,380 feet Junk measured N/A feet Effective Depth measured 5,040 feet Packer measured 1,390,4,980,5,472 feet true vertical 4,096 feet true vertical 1,368,4,044,4,471 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 485' 28" 485' 484' Surface 895' 13-3/8" 895' 894' 5,020 psi 2,260 psi Intermediate 1,430' 9-5/8" 1,430' 1,403' 5,750 psi 3,090 psi Production 5,700' 7" 5,700' 4,669' 7,240 psi 5,410 psi Liner 2,165' 5" 7,637' 6,350' 8,290 psi 7,250 psi Perforation depth Measured depth 3,535-3,988 feet 9 pp'� AR True Vertical depth 2,823-3,185 feet CANN �� MU f 3-1/2" 9.2#/L-80 1,415'(MD) 1,390'(MD) Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 5,098'(MD) 4,146'(TVD) AS1-X Ret.Pkr 1,390'(MD)1,368'(ND) Packers and SSSV(type,measured and true vertical depth) Prod.Pkr 4,980'(MD)4,044'(ND)3-1/2"EUE 8rd SSSV 414'(MD)414'(ND) ZXP Flex III Hgr Pkr 5,472'(MD)4,471'(ND) 12.Stimulation or cement squeeze summary: 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 1064 0 159 149 Subsequent to operation: 0 1556 0 70 42 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development0 Service El Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑ Gas 0 WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 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: 316-537 Contact Dan Marlowe(907)283-1329 Email dmarloweehilcorD.com Printed Name Stan W.Golis Title Operations Manager Signature y,,,,. J Phone (907)777-8356 Date t t l ! G 'Hip ll-023 (6 RBDMS V10 1 7 2016 Form 10-404 Revised 5/2015 7, ' ((4/((l Submit Original Only McArthur River Field 4 II • SCHEMATIC • Steelhead Platform Well M-17 Hilcorp Alaska,LLC Completed: 11/22/2015 CASING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM(MDrkb) 28" Structural 27 Surface 485' RKB to TBG Head 71.82' 13-3/8" 68 L-80 BTC 12.415 Surface 895' 9-5/8" 40 L-80 BIC 8.835 Surface 1,430' ill . 7" I 26 L-80 BTC-M 6.276 Surface 5,700' 28"Conductor 5"liner 18 L-80 H513 4.180" 5472' 7,637' ECP stage collar TUBING DETAIL A13-3/8"in 17 W Hole 3-1/2" 9.2 L-80 TC-II 2.992 Surf 1,415' ECP Stage Collar 3-1/2" 9.2 L-80 TC-II 2.992 4,975' 5,098' Est TOC Qd 920' *The 5",186,FJ liner has an ID of 4.276"&a drift of 4.155". The H513 connection has a 4.194"machined pin ID.The Baker ZXP Flex III hanger packer assembly has a TKC x H513 X over with a 4.180"machined ID.This represents the minimum ID in the 5"liner. ( Top Fish:Debris from 5"drillable bridge plugs. Bottom Fish: 2.5X15'Spiral Jet EJ gun,1-11/16"x 1.5 firing head,1-11/16"x 1.5'magnet,1-11/16"x 1'CCL,1-11/16"x 1'swivel,1-11/16" x 18'weight bar,1-3/8"x 22'rope socket. 4 2 11 , 9-5/8"in 12 Ya"Hole Jewelry Detail 3 - No. Item Depth OD ID Notes 13 3/8 x 28"ECP Stage Collar 454' Cemt'd to Surf 4 9 5/8 x 13 3/8 ECP Stage Collar 849' Attempt to Cemt to ML 1 SSSV 414' 5.375" 2.813" 5 2 GLM 1,362' 5.00" 2.813" 3 AS1-X Retrievable Packer 1,390' 5.870" 3.00" A Zane 4 X-Nipple 1,406' 4.50" 2.813" 5 WLEG 1,415' 4.50" 2.992" milt 41-- Top of tubing 6 Production Packer 4,980' 5.97" 3.900" Baker S-3 I ""s I r7:.=1 @ 4,975' 7 X Profile Nipple w/X-Plug 5,040' 4.50" 2.813" 6 - A. .- 8 WLEG(bottom) 5,098' 3.93" 2.960" 7 . 9 ZXP Flex III Hanger Packer 5,472' 5.250" 4.180" --� 10 5"Cement Retainer 7,213' »» »» Top of Cement at 7,200' 8 = C5 Zone TOC 5 276 = C7 Zone Perforation Detail MD TVD Date Zone ,� .'r , (SPF) Notes .1..7 3,535'-3,550' 2,823'-2,833' 10/29/16 A-3 6 r 3,577-3,592' 2,853'-2,865' 12/17/15 A 3 9 3,981'-3,988' 3,179'-3,155' 12/16/15 A 6 ,..,„ 7"Casing in 8 X"Hole 5,147'-5,167' 4,189'-4,206' 6/18/2012 C5 6 Isolated 5,229'-5,236' 4,260'-4,226' 6/15/2012 C7 4 Isolated I 7 D3B Zone(sqzd plugged) 5,782'-5,788' 4,740'-4,745' 11/29/2007 6 Squeezed,Ref SCMT Log 11/22/07 5,832'-5,856' 4,784'-4,805' 2/19/2008 D3B 5 Squeezed,112.5 bbls 15.8 ppg LXT 6,029'-6,042' 4,955'-4,967' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip 6,066'-6,073' 4,988-4,994' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip 6,169'-6,179' 5,078'-5,086' 6/1/2012 D6 4 2-1/2"Shogun Strip 60 deg Spiral Strip a_ 6,234'-6,240' 5,135'-5,140' 11/27/2007 6 Squeezed,Ref SCMT Log 11/22/07 D4 Zone 7,142'-7,155' 5,919'-5,930' 4/5/2010 014 6 SLB 2-1/2"PJ Omega HC 60°phasing = D4 Zone 7,296-7,308' 6,052'-6,062' 2/16/2008 D-16A 2-Sep Plugged/Squeezed thru cement retainer at 7213' Top of D6 Zone with 3.25 bbls of LXT cement and 2 bbls dumped on 7,361'-7,391' 6,108'-6,135' 2/13/2008 D-16C 2-Sep Primary top and dressed to 7200' Cement . 7,456-7,470' 6,191'-6,204' 12/21/2008 D-17 11 Isolated with 5"Posi-Set Plug at 7423'and 15.25 is 7034' dump D14 Zone gals(18')of bailed cement. 10 Top of Cement Plug at 7200' :-y 016A Zone(sqzd plugged) D16C Zone lsozd olueeedl � : D17 Zone(plugged) 5"Posi-Set plug at 7423'w/15.23 gals cmt placed w/dump bailer(TOC 5"Liner Shoe at 7637' tagged at 7405'ELM,2-11-081 6-1/8"Hole TD at 7670' MAX HOLE ANGLE: 56.4°@ Tangent 2,796'MD Note:Placed 2'of ceramic beads on top of sand fill @ 5,297. Revised: 11/16/16 by_ILL • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date M-17 Eline 50-733-20552-00 207-120 10/29/16 10/29/16 Daily Operations: 10/29/16-Saturday Arrive OSK heliport. Fly to Platform. Platform Orientation. PJSM and Permit. Offload boat, spot ELU on deck. RU ELU. PU GR/CCL log suite +Gun# 1 (15' x 2.50" OD Geo Razor, 6spf, 60 deg.). Rig to WH. PT lubricator and WLV= 250 LO/1500 HI. CCL to top shot= 12.30'. Initial T/IA/OA=40/75/90. Open swab valve and RIH to 3708'. Log up 3708' -2490' at 40 FPM to correlate and depth correct. Send correlation log LAS file for depth verification. Receive verification of log depth. RIH to 3708'. Log up to place shots on depth @ 3522.7' RKB (3522.7' + 12.3'= 3535.0') Pre-shot Tubing Press= 43 psi, Flow Rate = 1.40 MMSCFD. Fire Gun# 1 perforating 3535'-3550' RKB. POOH logging at 40 FPM to 3400' and then continue POOH. Post-shot Tubing Press=45 psi, Flow Rate = 1.46 MMSCFD. Hang up @ 1403' CCL depth with 11000#, 200#over pull (WLEG = 1415'). Unable to pull perf gun into tubing. Slack off wire, will not fall. Repeat 200#over pull and slack off with same. Notify Prod. Eng. & ELU Manager. Notify Production Operator and SI well. Pull to 1400#, still hung up. Slack off and no fall. Repeat pull to 1400#&slack off with same. Pull slow and work up towards 2600# rope socket fail. 2400#pull(1500#over pull)wire is free. PUH w/working GR log, appear to have BHA. POOH to surface. OOH. SI swab valve. Rig off WH, ELU BHA CCL/GR & Gun #1 returned to surface. Return well to production. RD SLU. Fly crew to beach.Job Ended. III • VOF Tyi • g;,i."\I'\�y/y..• THE STATE Alaska Oil and Gas ti ti, o ®® TT ee cc TT e� Conservation Commission _-4 1ZLr1 V���1 Sf�2 �� 333 West Seventh Avenue 1' `' '. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager Hilcorp Alaska, LLCscivisa MAR 0 4117: 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: McArthur River Field, Middle Kenai Gas Pool, TBU M-17 Permit to Drill Number: 207-120 Sundry Number: 316-537 Dear Mr. Golis: 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, /46 Cathy P.7Foerster Chair DATED this Z day of October, 2016. RBDMS 1,' OL I L 8 2016 . • • RECEIVED STATE OF ALASKA I I C T 1. 7 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 0 ' Other Stimulate ❑ Pull Tubing El Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development I], 207-120 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20552-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A • Will planned perforations require a spacing exception? Yes ❑ No 0 I Trading Bay Unit M-17• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594/ADL0018730' McArthur River Field/Middle Kenai Gas Pool 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): 7,670 - 6,380 - 5,040 - 4,096 , 858 psi 5,040 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 485' 28" 485' 484' Surface 895' 13-3/8" 895' 894' 5,020 psi 2,260 psi Intermediate 1,430' 9-5/8" 1,430' 1,403' 5,750 psi 3,090 psi Production 5,700' 7" 5,700' 4,669' 7240 psi 5,410 psi Liner 2,165' 5" 7,637' 6,350' 8,290 psi 7,250 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 3,577-3,988 . 2,853-3,185 3-1/2" 9.2#/L-80 1,415'&5,098' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): AS1-X Ret Pkr/Baker S-3/ZXP Flex III Hanger Packer& SSSV 1,390'(MD)1,368'(ND)4,9'80'(MD)4,044'(TVD)/5,472'(MD)4,471'(ND)&414' (MD)414'(ND) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 10/31/2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS i]' WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown o Abandoned El 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)2831329 Email dmarloweehilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature Stan Phone (907)777-8356 Date 10(11 ( 34,1 V COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number^ ' 5 Le 7 Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: OCT Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS 1,1J I L 8 2016 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /0--i-I 0/( iF t:. zs 1 ik, APPROVED BY f,.�/ Approved b 1`-'c�-- / COMMISSIONER THE COMMISSION Date:6 O , Io t,1'i5' "`q,41(% '''aaa... /�) a-- /0-2y'(b Submit Form and Form 10-403 Revised 11/2015 Approved application is valid 1 ortt S r n�hrr awe tPProv al. Attachments in Duplicate • Well Work Prognosis Well: M-17 Hileorp Alaska,LLC Date: 10/13/16 Well Name: Trading Bay Unit M-17 API Number: 50-733-20552-00 Current Status: Gas Well Leg: A-1 (West) Estimated Start Date: 10/31/2016 Rig: E-Line Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 207-120 First Call Engineer: Dan Marlowe Office:907-283-1329 Cell:907-398-9904 Second Call Engineer: Stan Golis Office:907-777-8356 Current Bottom Hole Pressure: 615 psi @ 2,823'TVD 0.218 psi/ft SIBP Maximum Expected BHP: 1,140 psi @ 2,823'TVD 0.404 psi/ft high case for new perfs Maximum Potential Surface Pressure: r 858 psi ' Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) **Well to be perforated well flowing Last Casing Test: 11/19/20151,500 psig at 1,390'for 30 minutes on chart Brief Well Summary: Well M-17 is a gas well completed in the A Sands.This project will add reshoot the existing A sands and add additional perfs in the A-3 sands. J E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line guns and perforate with well flowing per program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic McArthur River Field • SCHEMATIC • Steelhead Platform Well M-17 • II Hilcoru Alaska,LLC Completed: 11/22/2015 CASING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM(MDrkb) 28" Structural 27 Surface 485' RKB to TBG Head 71.82' 13-3/8" 68 L-80 BTC 12.415 Surface 895' 9-5/8" 40 L-80 BIC 8.835 Surface 1,430' r, 7" 26 L-80 BTC-M 6.276 Surface 5,700' 1 28"Conductor 5"liner 18 L-80 H513 4.180• 5472' 7,637' ECP Stage Collar TUBING DETAIL 13-3/8"in 1715"Hole 3-1/2" 9.2 L-80 TC-II 2.992 Surf 1,415' ECP Stage Collar 3-1/2" 9.2 L-80 TC-II 2.992 4,975' 5,098' Est TOC @ 920' 'The 5",189,F1 liner has an ID of 4.276"&a drift of 4.155". The H513 connection has a 4.194"machined pin ID.The Baker ZXP Flex III hanger packer assembly has a TKC x H513 X over with a 4.180"machined ID.This represents the minimum ID in the 5"liner. Top Fish:Debris from 5"drillable bridge plugs. Bottom Fish: 2,5X15'Spiral Jet EJ gun,1-11/16"x 1.5 firing head,1-11/16"x 1.5'magnet,1-11/16"x 1'CCL,1-11/16"x 1'swivel,1-11/16" x 18'weight bar,1-3/8"x 22'rope socket. 2 t 9-5/8"in 12%"Hole Jewelry Detail l iii 3 No. Item Depth OD ID Notes 13 3/8 x 28"ECP Stage Collar 454' Cemt'd to Surf 4 9 5/8 x 13 3/8 ECP Stage Collar 849' Attempt to Cemt to ML 1 SSSV 414' 5.375" 2.813" 5 2 GLM 1,362' 5.00" 2.813" 3 AS1-X Retrievable Packer 1,390' 5.870" 3.00" 4 X-Nipple 1,406' 4.50" 2.813" A Zone 5 WLEG 1,415' 4.50" 2.992" Top of tubing 6 Production Packer 4,980' 5.97" 3.900" Baker 5-3 I ;_1.pm t @ 4,975' 7 X Profile Nipple w/X-Plug 5,040' 4.50" 2.813" 6 - a• _- 8 WLEG(bottom) 5,098' 3.93" 2.960" 7 9 ZXP Flex III Hanger Packer 5,472' 5.250" 4.180" -- -- 10 5"Cement Retainer 7,213' »» »» Top of Cement at 7,200' 8 = C5 Zone TOC 5,276 C7 Zone ,p, -.4 , Perforation Detail < MD TVD Date Zone (SPF) Notes " 3,577'-3,592' 2,853'-2,865' 12/17/15 A 3 6 4�,'"_ 3,981'-3,988' 3,179'-3,185' 12/16/15 A6 6 9 '':',.',,1.,"" 5,147'-5,167' 4,189'-4,206' 6/18/2012 C5 6 Isolated 7"Casing in 8'S"Hole iii;,, 5,229'-5,236' 4,260'-4,226' 6/15/2012 C7 4 Isolated c.arri `i 5,78T-5,788' 4,740'-4,745' 11/29/2007 6 Squeezed,Ref SCMT Log 11/22/07 v' D3B Zone(sqzd plugged) 5,832'-5,856' 4,784'-4,805' 2/19/2008 D3B 5 Squeezed,112.5 bbls 15.8 ppg LXT 6,029'-6,042' 4,955'-4,967' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip s"!*' K 6,066'-6,073' 4,988-4,994' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip 6,169'-6,179' 5,078'-5,086' 6/1/2012 D6 4 2-1/2"Shogun Strip 60 deg Spiral Strip 6,234'-6,240' 5,135'-5,140' 11/27/2007 6 Squeezed,Ref SCMT Log 11/22/07 z 7,142'-7,155' 5,919'-5,930' 4/5/2010 014 6 SLB 2-1/2"PJ Omega HC 60°phasing 12 _ D4 Zone 7,296'-7,308' 6,052'-6,062' 2/16/2008 D-16A 2-Sep Plugged/Squeezed thru cement retainer at 7213' a;' with 3.25 bbls of LXT cement and 2 bbls dumped on ; D4 Zone 7,361'-7,391' 6,108'-6,135' 2/13/2008 D-16C 2-Sep top and dressed to 7200' Top of 'tsx•5�`.t a D6 Zone Primary T7,456'-7,470' 6,191'-6,204' 12/21/2008 0-17 11 Isolated with 5"Posi-Set Plug at 7423'and 15.25 Cement A4 gals(18')of dump bailed cement. is 7034' :4"1C-76,+ 4 D14 Zone .. `.::,g Top of Cement Plug at 7200' 10 D16A Zone(sqzd plugged) seas, D16C Zone tuned olueeedl e117 Zone(plugged) A , 5"Posi-Set plug at 7423'w/15.23 gals ant placed w/dump bailer(TOC 5"Liner Shoe at 7637' tagged at 7405'ELM,2-11-081 6-1/8"Hole TD at 7670' MAX HOLE ANGLE: 56.4°@ Tangent 2,796'MD Note:Placed 2'of ceramic beads on top of sand fill @ 5,297'. Revised:1/13/16 by JLL McArthur River Field • PROPOSED • Steelhead Platform Well M-17 v II Hilcorp Alaska,LLC Completed: 11/22/2015 CASING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM(MDrkb) 28" _ Structural 27 Surface 485' RKB to TBG Head 71.82' 13-3/8" 68 L-80 BTC 12.415 Surface 895' 9-5/8" 40 L-80 BTC 8.835 Surface 1,430' 7" 26 L-80 BTC-M 6.276 Surface 5,700' 7,637' ill 1 • 28"Conductor 5"liner 18 L-80 H513 4.180" 5472' ECP stage collar TUBING DETAIL 13-3/8"in 17'A"Hole 3-1/2" 9.2 L-80 TC-II 2.992 Surf 1,415' ECP Stage Collar 3-1/2" 9.2 L-80 TC-II 2.992 4,975' 5,098' *The 5",185,FJ liner has an ID of 4.276"&a drift of 4.155". The H513 connection has a 4.194"machined pin ID.The Baker ZXP Flex III Est TOC @ 920' hanger packer assembly has a TKC x H513 X over with a 4.180"machined ID.This represents the minimum ID in the 5"liner. • Top Fish:Debris from 5"drillable bridge plugs. Bottom Fish: 2.5X15'Spiral Jet EJ gun,1-11/16"x 1.5 firing head,1-11/16"x 1.5'magnet,1-11/16"x 1'CCL,1-11/16"x l'swivel,1-11/16" x 18'weight bar,1-3/8"x 22'rope socket. 2 I , 9-5/8"in 12 4"Hole Jewelry Detail 3 I I - No. Item Depth OD ID Notes 13 3/8 x 28"ECP Stage Collar 454' Cemt'd to Surf 4 9 5/8 x 13 3/8 ECP Stage Collar 849' Attempt to Cemt to ML 1 SSSV 414' 5.375" 2.813" 5 / ------ex2 GLM 1,362' 5.00" 2.813" 3 AS1-X Retrievable Packer 1,390' 5.870" 3.00" A Zone 4 X-Nipple 1,406' 4.50" 2.813" 5 WLEG 1,415' 4.50" 2.992" imp. o tubing 6 Production Packer 4,980' 5.97" 3.900" Baker S-3 I Lag I @ 4,975' 7 X Profile Nipple w/X-Plug 5,040' 4.50" 2.813" 6 - - ! - 8 WLEG(bottom) 5,098' 3.93" 2.960" 7 Tri 9 ZXP Flex III Hanger Packer 5,472' 5.250" 4.180" ',--- 10 5"Cement Retainer 7,213' »» »» Top of Cement at 7,200' 8 - C5 Zone TOC 54276 - C7 Zone f .9 ,,, Perforation Detail '_. MD TVD Date Zone (SPF) Notes „1+ � ±3,535'-±3,550' ±2,823'-±2,833' Future A-3 Proposed r +3,577'-±3,592' ±2,853'-±2,865' Future A 3 Re-perf 9 ;" 7"Casing in8h"Hole ±3,981'-±3,988' ±3,179'-±3,185' Future A6 Re-perf '-.14,;41 if5,147'-5,167' 4,189'-4,206' 6/18/2012 C5 6 Isolated 5,229'-5,236' 4,260'-4,226' 6/15/2012 C7 4 Isolated 77:44,',A, D3B Zone(sgzd plugged; 5,782'-5,788' 4,740'4,745' 11/29/2007 6 Squeezed,Ref SCMT Log 11/22/07 ; 5,832'-5,856' 4,784'-4,805' 2/19/2008 D3B 5 Squeezed,112.5 bbls 15.8 ppg LXT i�+ 6,029'-6,042' 4,955'-4,967' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip r f4 :, 41 6,066-6,073' 4,988-4,994' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip 1.0, 6,169'-6,179' 5,078'-5,086' 6/1/2012 D6 4 2-1/2"Shogun Strip 60 deg Spiral Strip fir° 6,234'-6,240' 5,135'-5,140' 11/27/2007 6 Squeezed,Ref SCMT Log 11/22/07 Da Zone 7,142'-7,155' 5,919'-5,930' 4/5/2010 014 6 SLB 2-1/2"PJ Omega HC 60°phasing , 7,296'-7,308' 6,052'-6,062' 2/16/2008 D-16A 2-Sep Plugged/Squeezed thru cement retainer at 7213' D4 Zone with 3.25 bbls of LXT cement and 2 bbls dumped on Top of ,;iii.9,;241 D6 Zone 7,361'-7,391' 6,108'-6,135' 2/13/2008 D-16C 2-Sep top and dressed to 7200' Primary s Cement7,456'-7,470' 6,191'-6,204' 12/21/2008 0-17 11 Isolated with 5"Posi-Set Plug at 7423'and 15.25 is 7034' a pia zone ,agals(18')of dump bailed cement. ' Top of Cement Plug at 7200' _,.,_ D16A Zone(sgzd plugged) 1ac, --- D16C Zone Isazd alueeedl i _..: 017 Zone(plugged) A , 5"Posi-Set plug at 7423'w/15.23 gals amt placed w/dump bailer(TOC 5"Liner Shoe at 7637' tagged at 7405'ELM,2-11-081 6-1/8"Hole TD at 7670' MAX HOLE ANGLE: 56.4°@ Tangent 2,796'MD Note:Placed 2'of ceramic beads on top of sand fill @ 5,297'. Revised: 10/13/16 byJLL 2.rst-x20 w 0 27i6b II Debra Oudean Hilcorp Alaska, LLC AK_GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 Hilcurp tbu.k;I.1.IA, Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE: 5/13/2016 DATA LOGGED 5 ittizo1G K.BENDER To: AOGCC RECEIVED Makana Bender 333 W. 7th Ave. Ste#100 MAY 13 201€i Anchorage, AK 99501 AOGCC DATA TRANSMITTAL TBU M-17 Prints TUBING JET CUTTER CEMENT BOND LOG CD M-17_CBL_17NOV15.las 12/31/2015 8:59 AM LAS File 3,688 KB M-17_CBL_17NOV15.pdf 12/31/2015 1:15 PM PDF-XChange View... 7,648 KB M-17_CBL_17NOV15_img.tiff 12/31/2015 1:13 PM TIFF File 20,560 KB -_ M-17_JETCUTTER_17NOV15.pdf 12/31/2015 1:17 PM PDF-XChange View... 1,186 KB M-17_JETCUTTER_17NOV15_Correlation.las 12/31/2015 1:20 PM LAS File 53 KB M-17_JETCUTTER_17NOV15_Cutting.las 12/31/2015 1:19 PM LAS File 53 KB M-17_JETCUTTER_17NOV15_inig.tiff 12/31/2015 1:16 PM TIFF File 1,991 KB SCANNED JUN 1 3 2016. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Receiv-. : ✓� 6e.../ Date: ' V STATE OF ALASKA AlltA OIL AND GAS CONSERVATION COM ION .' REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing Cl Operations shutdown ❑ Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program Cl Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Complete C 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 207-120 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20552. f 7.Property Designation(Lease Number): 8.Well Name and Number: Yf .. ADL0017594/ADL0018730 Trading Bay Unit M-17 y 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): JAN A 5 7.u N/A McArthur River Field/Middle Kenai Gas Pool 11.Present Well Condition Summary: , 1, Total Depth measured 7,670 feet Plugs measured 5,040 feet true vertical 6,380 feet Junk measured N/A feet Effective Depth measured 5,040 feet Packer measured 1,390,4,980,5,472 feet true vertical 4,096 feet true vertical 1,368,4,044,4,471 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 485' 28" 485' 484' Surface 895' 13-3/8" 895' 894' 5,020 psi 2,260 psi Intermediate 1,430' 9-5/8" 1,430' 1,403' 5,750 psi 3,090 psi Production 5,700' 7" 5,700' 4,669' 7,240 psi 5,410 psi Liner 2,165' 5" 7,637' 6,350' 8,290 psi 7,250 psi Perforation depth Measured depth 3,577-3,988 feet SCM True Vertical depth 2,853-3,185 feet 3-1/2" 9.2#/L-80 1,415'(MD) 1,390'(TVD) Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 5,098'(MD) 4,146'(ND) AS1-X Ret.Pkr 1,390'(MD)1,368'(ND) Packers and SSSV(type,measured and true vertical depth) Prod.Pkr 4,980'(MD)4,044'(TVD)3-1/2"EUE 8rd SSSV 414'(MD)414'(ND) ZXP Flex III Hgr Pkr 5,472'(MD)4,471'(ND) 12.Stimulation or cement squeeze summary: 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: 0 496 0 290 58 Subsequent to operation: 0 1565 0 110 185 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development 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 ❑ 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: 315-523 Contact Trudi Hallett(907)777-8323 Email thallett(a hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature ,4 Li(- eL Phone (907)777-8356 Date ii (5 I 74, 3_ Z -R, RBDMS it.. JAN 2 1 2016 Form 10-404 Revised 5/2015 ,477e Submit Original Only • SCHEMATIC • McArthur eadRiverPlatformField • Well M-17 tt;le°=u Alaska,LLC Completed: 11/22/2015 CASING DETAIL SIZE WT GRADE CONN MIN ID TOP _ BTM(MDrkb) 28" Structural 27 Surface 485' RKB to TBG Head 71.82' 13-3/8" _ 68 _ L-80 BTC 12.415 Surface 895' 9-5/8" 40 L-80 BTC 8.835 Surface _ 1,430' 7" 26 L-80 BTC-M 6.276 Surface 5,700' 7,637' 1 id 28"Conductor 5"liner 18 L-80 H513 4.180* 5472' MN ECP Stage Collar TUBING DETAIL 13-3/8"in 1714"Hole 3-1/2" 9.2 L-80 TC-II 2.992 Surf 1,415' ECP Stage Collar 3-1/2" 9.2 L-80 TC-II 2.992 4,975' 5,098' Est TOC @ 920' `The 5",189,F1 liner has an ID of 4.276"&a drift of 4.155". The H513 connection has a 4.194"machined pin ID.The Baker ZXP Flex III hanger packer assembly has a TKC x H513 X over with a 4.180"machined ID.This represents the minimum ID in the 5"liner. Top Fish:Debris from 5"drillable bridge plugs. Bottom Fish: 2.5X15'Spiral Jet EJ gun,1-11/16"x 1.5 firing head,1-11/16"x 1.5'magnet,1-11/16"x 1'CCL,1-11/16"x 1'swivel,1-11/16" x 18'weight bar,1-3/8"x 22'rope socket. t 2 16 , 9-5/8"in 12 Y.."Hole Jewelry Detail - ' 3 = 137 01 kkfj No. Item Depth OD ID Notes 13 3/8 x 28"ECP Stage Collar 454' Cemt'd to Surf 4 9 5/8 x 13 3/8 ECP Stage Collar 849' Attempt to Cemt to ML 1 SSSV 414' 5.375" 2.813" 5 2 GLM 1,362' 5.00" 2.813" 3 AS1-X Retrievable Packer 1,39d 5.870" 3.00" _ 4 X-Nipple 1,406' 4.50" 2.813" A Zone 5 WLEG 1,415' 4.50" 2.992" I Top of tubing 6 Production Packer 4,980 5.97" 3.900" Baker S-3 6 i - t @ 4,975' 7 X Profile Nipple w/X-Plug 5,040' 4.50" 2.813" --1-2; 8 - 5 8 WLEG(bottom) 5,098' 3.93" 2.960" . l�P"--0,--E9 ZXP Flex III Hanger Packer 5,472' 5.250" 4.180" 7 .ice r 10 5"Cement Retainer 7,213' »» »» Top of Cement at 7,200' 8 - C5 Zone "`_"'- TOC5,276 C7 Zone -„ Perforation Detail MD TVD Date Zone (SPF) Notes 3,577'-3,592' 2,853'-2,865' 12/17/15 A 3 6 CC)Pn(=A.J y 3,981'-3,988' 3,179'- = • 15 A 6 6 / 4:::: 4411. 7"Casing in 8'A"Hole - - - J. 4,189'4,206 6/18/2012 "-C-5- 6 Isolated 5,229'-5,236' 4,260'-4,226' 6/15/2012 C7 4 Isolated 5,782'-5,788' 4,740'-4,745' 11/29/2007 _ 6 Squeezed,Ref SCMT Log 11/22/07 i 738 Zone(sqzd plugged, 5,832'-5,856' 4,784'-4,805' 2/19/2008 D3B 5 Squeezed,112.5 bbls 15.8 ppg LXT 6,029'-6,042' 4,955'-4,967' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip 6,066-6,073' 4,988-4,994' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip 6,169'-6,179' 5,078'-5,086' 6/1/2012 D6 4 2-1/2"Shogun Strip 60 deg Spiral Strip 6,234'-6,240' 5,135'-5,140' 11/27/2007 _ 6 Squeezed,Ref SCMT Log 11/22/07 7,142'-7,155' 5,919'-5,930' 4/5/2010 014 6 SLB 2-1/2"PJ Omega HC 60°phasing D4 Zone 7,296-7,308' 6,052'-6,062' 2/16/2008 D-16A 2-Sep Plugged/Squeezed thru cement retainer at 7213' D4 Zone with 3.25 bbls of LXT cement and 2 bbls dumped on 7,361'-7,391' 6,108'-6,135' 2/13/2008 0-16C 2-Sep top and dressed to 7200' Top of D6 Zone - Primary 7,456-7,470' 6,191'-6,204' 12/21/2008 D-17 11 Isolated with 5"Posi-Set Plug at 7423'and 15.25 Cement gals(18')of dump bailed cement. is 7034' 014 Zone Top of Cement Plug at 7200' 10 716A Zone(sqzd plugged) >3r:2, D16C Zone(said olueeedl le a 1.7 Zone(plugeed) 5"Posi-Set plug at 7423'w/15.23 gals cmt placed w/dump bailer(TOC 5"Liner Shoe at 7637' tagged at 7405'ELM,2-11-081 6-1/8"Hole TD at 7670' MAX HOLE ANGLE: 56.4°@ Tangent 2,796' MD Note:Placed 2'of ceramic beads on top of sand fill @ 5,297'. Revised: 1/13/16 byJLL • • Hilcorp Alaska, LLC Well Operations Summary Well Name • PI Number Well Permit Number Start Date End Date M-17 Moncla 404 50-733-20552-00 207-120 11/12/15 12/17/15 Daily Operations: 11/12/2015-Thursday R/U LIGHTS ON RIG CARRIAGE. CLOSE IN FRONT OF RIG W/TARP AND SECURE SAME. WIRE UP KOOMEY UNIT TO RIG ELEC PANEL. INSTALL LINES TO KOOMEY REMOTE. BUILD STEPDOWN FOR STAIRS. BUILD GRATING COVERS FOR RACKING MAT BEAM. ASSIST TOTAL SAFETY RIGGING UP SAFETY EQUIP. R/U TANK CANOPIES. INSTALL GRATING AROUND KOOMEY UNIT. SECURED SAME. BEGAN LOADING WELL WITH FIW DOWN ANNULUS. CLEARED OFF PIPE RACKS WITH CRANE. CONNECTED TARPS OVER RIG CARRIER. PLACED HEATERS AND RAN TRUNK LINES TO MUD PUMP, ACCUM HOUSE AND CARRIER. CONTINUED WINTERIZING. RUNNING ELECTRICAL, HOSES AND MISC LINES. OPENED WELL AND MONITORED FOR FLOW. NOS REP INSTALL BPV. N/D TREE. LAID DOWN TREE AND ASSISTED NOS REP INSTALLING BLANKED TEST SUB IN HANGER. N/U 35' OF 13 5/8" 5M RISOR WI MUD CROSS, BLIND AND 2 7/8" x 5" VARIABLE PIPE RAMS AND ANNULAR. CONTINUED TIGHTENING BREAKS WHILE HANGING RIG FLOOR. 11/13/2015 - Friday Finished hanging rig floor and tightening BOP flange bolts. Wrapped BOP stack with tarping and ran in heater trunks. Welder continued building steps and handrails as needed. Rig electrician continued running services to accessory equipment. Put up wind walls around rig floor and crew covered active tank with it's tarp. R/U Hilcorp McCoy tongs. Offloaded HLS E-Line equipment from M/V Titon. Installed vent line on gas buster and spotted test pump in place. R/U same. Reroute heater trunks to mud pump and rig carriage. R/U hose from production to rig tank to take on FIW. M/U test jt w/x-overs on btm. Assisted NOS screwing into blank sub in hanger. M/U pumpin, S/V and IBOP in top of test jt. Filled stack and choke manifold w/ FIW and began working thru BOPE pretest repairing leaks as neccessary. 11/14/2015 -Saturday Finished pretesting BOPs 250#s low/2500#s high. Welder building steps as needed and modifying V-door. Focused on housekeeping and prep for AOGCC witnessed BOPE test and possible rig inspection.Tested all BOPE to 250#s low/ 2500#s high as per AOGCC and Hilcorp requirements. Performed successful accumulator draw down. Test witnessed by Mr. Matthew Herrera/AOGCC. B/D test jt. Fire and abandon drill performed. Assisted welder spotting and welding V- door in place prior to opening well. Pulled BPV and M/U landing jt- backed out hanger pins. Pulled 10k over string weight and set on slips. Held PJSM with rig, crane and HLS crew. R/U E-Line and full lubricator. M/U 2.50"jet cutter and pulled inside lubricator-tested to 1500#s. TIH and correlated on depth-cut tubing, at 4975'- 5' above pkr. ! • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date M-17 Moncla 404 50-733-20552-00 207-120 11/12/15 12/17/15 Daily Operations: 11/15/2015 -Sunday POOH w/ HLS ELine and R/D same. Line up to reverse hole volume. Circulated 5400 stks (200 bbls) at 2 BPM 90 PSI thru active tank. Minimual trace of oil initially. Shut down pump. Pulled hanger to floor and NOS Rep B/D same. POOH to SSSV laying down singles and recovering 1/4" control line. Continued OOH racking back 20 stands of 3 1/2" 9.2# L-80 TC- 2 production string. Worked M/V Titon offloading 3 1/2" PH-6 workstring,Tripoint production pkr, side-pocket mandrel (w/dummy) and SSSV. Continue POOH w/ recovered 3 1/2"TC-2 production string, pups and mandrels. Assist welder modify v-door stop. Continue POOH w/ recovered 3 1/2" TC-2 production string, pups and mandrels.All personnel muster due to gas alarm. Finish pooh with 3-1/2" TC-II prod tbg and jewelry. Total recovered=4,964' 147 jts, 1 cut piece, (4) GLM and SCSSV. R/D McCoy tongs. Rig up BJ'S and foster tongs. M/U 6" bit and 7' scraper assy. P/u 3- 1/2" PH6 out of v-door and TIH, Strap and rabbit same. 11/16/2015- Monday TIH w/bit &scraper picking up 3 1/2" 12.95# PH-6 workstring-strapping, drifting and torqueing to 6000#s. Tagged at 4,979' (PM). P/U 1' off bottom. R/U hoses to reverse hole clean. Pump out return tank to Trading Bay, clean and fill same with 8.5# FIW. Displace well with 8.5# FIW @ 2 bpm 250 psi until returns clean. Total pumped to Trading Bay= 370 bbls. R/U testing equipment and test "x" plug in tbg to 1500 psi for 30 minutes on chart dated 11-17-2015. Rig down testing equipment. Pooh with bit & scraper racking back workstring. 11/17/2015 -Tuesday B/D bit& scraper. Held PJSM w/ rig, crane & HLS crew. R/U HLS E-Line. TIH w/3 1/8" Radial Bond Tool and recorded cement bond log from 4,400'to 495'. Files sent to Operations Engineer. Stoodby while Hilcorp and AOGCC discuss bond log. Received variance from AOGCC to continued on with planned procedure without squeezing 7" casing. TIH w/ 79 stands of 3 1/2" PH-6 workstring w/ muleshoe on btm. Pooh w/3-1/2" PH-6 and laydown same. M/U Tri-point 7" DLH hydraulic set retrievable packer as per Tri-point Rep. M/U gas lift mandrel ldd w/dummy. TIH w/3-1/2" TC-II 9.2# production tbg out of derrick. Strap and rabbit same. • r II Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date M-17 Moncla 404 50-733-20552-00 207-120 11/12/15 12/17/15 Daily Operations: 11/18/2015 -Wednesday Continued RIH w/Tripoint DLH Hydraulic set Retrievable pkr. M/U Baker TE-5 SSSV in string and could not screw control line fitting into threads in body of valve. Called Baker and requested a tap to clean out threads. Received starter and intermediate taps- no finishing tap received. Taped threads with available taps but failed in stopping leak at 1/4" control line entry. Picked up SSSV that was pulled with recovered production string and attempted to function valve (failed to function old valve). Called to check on availability of finishing tap but was initially informed that they did not have one. Baker later sent a finishing tap to the heliport and it was flown out to platform. Tapped threads with finishing tap and achieved a successful 3000#test on SSSV. Continued running in remainder of prod string. R/D Foster tongs and R/U McCoy tongs to M/U hanger. M/U hgr and NOS Rep terminate control line to same. Pollard Rep. test line to 4000 psi "ok". Land hgr and assist NOS Rep run in hgr pins.Tri-Point Rep drop packer setting bar. Pressure up on tbg as per Tri-Point Rep procedures and set 7" DLH packer @ 1,398' ELM. Final setting pressure= 3800 psi (hold for 30 mins). R/U hoses and test equipment to casing valve. Test packer to 1500 psi for 30 mins on chart dated 11-19-2015. R/D hoses and test equipment. Pull landing jt. and assist NOS Rep install BPV. R/D Mc Coy tongs and beaver slide. R/D rig floor and remove same. Began N/D 13-5/8" bops and riser. 11/19/2015-Thursday N/D 13 5/8" BOP stack to wellhead. Began B/D heating units, picking up trunk lines and fluid sys hoses preparing to move W/O equipment. NOS Rep prepped tb head to receive tree while Pollard R/U partially. N/U tree and plumbed into prod facility using chain hoist. Void tested hanger to 500#s/5 mins and 5000#s/15 mins. Piped in air to actuator and opened same. Pulled BPV and set 2-way check. Tested tree to 3000#s/ 15 mins. Pulled 2-way check. R/U Pollard SL w/full lubricator. M/U 2.25"JDC pulling tool and RIH to 1,332' (SLM). Latched drop bar and POOH. No recovery of bar, pin was sheared in pulling tool. Repinned pulling tool and TBI to 1,332' and latched bar. POOH recovering drop bar. M/U 2.73" GS Pulling tool and TIH to 1,337'. Latched plug and started OOH. Could not pass plug thru hanger(hanger was drifted with 2.867" drift prior to RIH). Checked valve positions and dumped glycol down tree. Still unable to pass plug thru hanger. At that point decision was made to push PX plug to btm and shear off of it leaving it in hole. Started downhole with plug but it now will not pass thru SSSV. Attempted to jar PX plug thru SSSV but failed. Beat down and released from plug. POOH and M/U 2.72" GR SU pulling tool and TIH to plug in SSSV. Latched and jarred plug free. POOH to tight spot and wedged plug,jarred off plug and POOH w/SL. M/U pkr setting bar on 2.04" RB SU pulling tool. TIH landing bar inside PX plug.Jarred plug down and pushed to SSSV. Attempted to jar thru with no success. POOH and added additional stem.TIH but failed to drive plug thru SSSV. POOH and R/D Pollard S/L. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date M-17 Moncla 404 50-733-20552-00 207-120 11/12/15 12/17/15 Daily Operations: 11/20/2015- Friday BPV was set and tree was N/D, separating actuator valve and flow line. Removed BPV, hanger inspected and drifted w/ 2.867" nylon drift. Drift was then lowered to a depth of 13' where it set down-this measurement puts us— 1' below a pup jt connection (hanger .90' + pup 11.17' = 12.07'). Possible over torqued connection or smashed tube. Set BPV. N/U tree plus actuator and flow line. Began winterization. R/U Pollard S/L while awaiting arrival of swaging tools to attempt to open tight spot. Continued hooking up circ system and running trunks to W/O components, firing up heaters in case we have to pull completion. 1430 hrs worked M/V Titon unloading S/L tools+ items needed to rerun completion. Total Safety R/U and tested gas alarm system. M/U Pollard RS, 1 3/4" stem x 2, knuckle, oil and spang jar w/2.80" swage. Pulled inside lubricator and tested to 2500#s. Opened well and TIH to 49' (SLM from main deck, —the same depth found with drift). Set down and started beating on tight spot. Could not make hole or wedge tool. POOH- no marks or scarring on swage. M/U 2.750" swage and RIH to 384' (SLM) without touching tight spot. POOH w/S-line. Secured well. R/D pollard s-line equipment and NOS rep install BPV. Nipple down production tree, pull and secure same. Assist NOS rep prep well head and m/u x-over in hanger for test jt. Stack 13-5/8" riser, mud cross and bops. Tighten all breaks. Hung rig floor and built support around same. 11/21/2015 -Saturday Began installing wind walls on rig floor and winterization around BOP stack but 35-38 MPH winds halted our attempts till 8:30 AM. Checked and tightened BOP stack bolts as needed. Received verbal permission from Mr. Regg/AOGCC at 45 AM test BOPE whenever we're ready-without witness. Mounted wind walls on rig floor and winterization around BOPs. Ran in trunk lines and started heating up BOPs. Rewired lighting in rig carrier, mud pump, and active P)1 tank- ran trunk lines to same. R/U Hilcorp McCoy tongs and moved elevators, slips and work plate to floor. M/U test jt. assist NOS rep screw test jt into hgr and finish rigging up test equipment. Shell test bops and fix leaks as required.Test 19.41— 13-5/8" x 5m Bops and surface equipment as per AOGCC and HILCORP specs 250 low/2500 high. Perform Koomey draw down "ok". R/D test equipment, pull test jt and assist NOS Rep pull bpv. • • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date M-17 Moncla 404 50-733-20552-00 207-120 11/12/15 12/17/15 Daily Operations: 11/22/2015-Sunday M/U landing jt w/SV and backed out hold down pins. P/U to 60k and pkr released (40k over pull). Pulled hanger to floor and worked control lines-attaching to spool and pressuring up to 3800#s (while POOH). Pulled to connection on c 12' pup below hanger and B/O same. Found that connection had been over torqued (2.867" drift would not pass in box or pin). No damage to tube. POOH removing bands and spooling up 1/4" control line to SSSV. Worked control line and B/O pup in top of SSSV. Recovered PX plug sitting in top of valve. Finished POOH w/production string. B/O X- nipple/reentry guide assembly from old pkr and M/U same on new AS1-X mechanical set pkr.TIH w/3 1/2" 8rd WLEG, 3 1/2" 8rd pup, 3 1/2" 8rd X-Nipple (2.813"), 3 1/2" 8rd pup, 5.870" AS1-X mechanical set pkr, 3 1/2" 8rd pup, 8rd x TC2 X-Over, 3 1/2"TC2 pup, 3 1/2" TC2 GLM w/dummy, 3 1/2" TC2 pup, 29 jts 3 1/2" 9.2#TC2 tb. M/U 3 1/2" 11.73'TC2 pup, 3 1/2" Baker TE-5 TC2 SSSV, 3 1/2" 11.73' TC2 pup in string. Connect 1/4" control line to valve and tested same to 3800#s for 30 mins. R/I 10 more jts of 3 1/2" 9.2#TC2 tb banding control line top and btm of each connection.Assisted NOS rep M/U hanger and terminating control line to SSSV. Functioned SSSV and test line to 4000 psi. Set Tri-Point AS1- X mech-set packer at 1,390' as per Tri-Point Rep. Landed hgr and assisted NOS Rep running in hanger pins. R/U Pollard S/L and M/U RS, 1 1/2" stem x 2, knuckle, oil & spang jars w/2.80" swage. Test lubricator to 1500 psi and RIH to 2,000' (SLM)- POOH w/S/L. R/U test equipment to casing and tested annulus to 1500 psi for 30 mins on chart dated. M/U 2 3/4" Daniel K/O tool on S/L(with same tool string) and rih w/same to GLM @ 1,362'. Made several attempts to latch dummy w/ no success. POH w/S/L- M/U 2 3/4" OK-1 tool and RIH- unable to latch dummy. POOH w/S/L and consult with Pollard office. Re-dressed tool and RIH- latched dummy and POOH. M/U 2 3/4" running tool and 3/16" valve- RIH w/same and set in GLM @ 1,362'. POOH R/D/R S/L. Pulled landing jt and assisted NOS rep installing BPV. Cleared rig floor and removed wind walls- started rigging down same. 11/23/2015- Monday R/D rig floor. N/D BOP stack. B/D circ lines and heaters, picking up trunk lines, began disconnecting electrical services to components.Assisted production N/U tree w/actuator and flow line. NOS void tested hanger to 500#s/5 mins- 5000#s/ 15 mins. Quadco and Total Safety R/D their systems. Pulled BPV and set 2-way check-shell tested tree to 3000#s/ 15 mins. Pulled 2-way check and turned well over to production. 12/16/2015-Wednesday Mobe e-line crews t/ Platform, orientate, PJSM, R/U e-line, p/t lub t/2500 good,RIH w/GR/CCL, 2 1/2" guns, 6 SPF, 60deg phasing, t/4000', log correlation pass, send t/town, verify & adjust. Log guns on depth w/top shot @ 3981', btm shot @ 3988', fired guns, good indication at surface guns fired, no immediate pressure change. POOH, I/d guns, all shots fired, secure well, turn over t/ production. 12/17/2015-Thursday PJSM, r/u 2 1/2", 6 SPF, 60 deg phasing guns, rih t/3700', log f/correlation, adjust, send t/town t/verify good. Log guns on depth w/top shot @3577', btm shot @3592', fire guns, good indication guns fired on surface, pressure increase on well, POOH, all shots fired, r/d w/l, remove bridge & replace upper well bay hatch cover. • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, December 02, 2015 8:53 AM To: 'Ted Kramer' Cc: Trudi Hallett(thallett@hilcorp.com) Subject: RE: M-17 Perforating Plan - Part of Sundry# 315-523, PTD#207-120 Ted, Thanks for the update and clarification for your proposed perforating operation on M-17. I don't see any issues with using lease gas to pressure up the tubing in order to push down the fluid level if needed.With a lot of open casing below the tubing tail you don't have a lot of options to unload well without CT. I will attach the email and procedure as an amendment to the sundry 315-523 in our well file.As the perforations intervals are the same an updated sundry is not required. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC SCONE° AUG 1 0 2016' 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: Wednesday, December 02, 2015 6:24 AM To: Schwartz, Guy L(DOA) Subject: M-17 Perforating Plan - Part of Sundry # 315-523, PTD # 207-120 Guy, I believe Trudi Hallett had sent you a note about perforating the above well. I wanted to further clarify how we plan to do so. I wanted to make you aware that the Steelhead is seeing a loss in reservoir pressure in a lot of its wells. Several are below their unloading rate for liquid due to the large ID tubing that was in the wells when originally completed. These depleted zones have made the search for high pressure bypassed gas even more difficult. The search is further compounded by the fact that there is now only one coiled tubing vendor in the inlet which has made the use of coil and nitrogen to jet in wells problematic because that unit is quite costly to mobilized and is not currently staffed. I say this to preface why we are going to perforate this well in the attached fashion. The goal since a lot of our zones are partially depleted, is to have as little hydrostatic above the perforations as possible. Since we cannot blow the well dry, on the first set of perfs (A-6), We plan to perforate and then flow the well and see what the A-6 perfs will give up. If the well does not flow. We will put gas pressure on the well to force the fluid into the formation to reduce the hydrostatic head. We will then place a plug over the perfs to eliminate the water in the well bore. We then will move up to the next set of perfs(A-3)and shoot those with little to no hydrostatic over the perfs. Subsequent perforations will be shot and 1 li flow tested in this fashion. Plugs will be set over intervals that are known to con ute water in offset wells to minimize the chance of crossflow. This will require a good working knowledge of where the fluid level is before and after each set of perforations are shot. Therefore multiple tags for fluid will be required. I have attached for your use, a perforation plan showing what intervals we plan to shoot, and where we plan to set plugs to prevent water crossflow between wells. I have also attached a well schematic that shows the current completion and the intervals we plan to shoot. If we find gas in commercial quantities,we will stop the process and produce the well. If we encounter an interval that produces a lot of water, we will pressure up on the well and set an additional plug to isolate it before proceeding up the hole to the next interval. We plan to proceed as soon as the plugs come in that we have on order. Please let me know if you have any questions or concerns. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 2 • • Well Work Prognosis Well: M-17 iuleorp Alaska,ILC Date: 12/01/15 Well Name: Trading Bay Unit M-17 API Number: 50-733-20552-00 Current Status: Gas Well Leg: A-1 (West) First Call Engineer: Ted Kramer Office:907-777-8420 Cell: 985-867-0665 Second Call Engineer: Jim Young Office:907-777-8404 Cell:907-903-8010 Current Bottom Hole Pressure: 562 Psi hydrostatic with fluid level at GLM Maximum Expected BHP: 1,500 psi(Based on normally pressured intervals) Max.Anticipated Surface Pressure: 1,160 psi. (Based on a 0.1 psi pressure gradient). Procedure: 1. Gas-lift fluid off well and bleed pressure off tubing to< 10psig. 2. RU E-line. RIH, note fluid level and perforate the A-6 ( 3,981 to 3,988 ) interval with well open to separator. • Monitor pressure/gas flow for at least 1 hour,and find the fluid level after perforating. • If the interval proves to be non-productive, perform the following: i. Connect gas lift gas to the tubing and pressure up on the well to force water into the A- 6 perforations. ii. RU E-line, RIH with dummy perf gun and tag fluid level to verify. Adjust gas pressure to achieve a fluid level of 3700' MD. iii. POH with E-line, PU Plug, RIH (note Fluid level)and Set Plug @ 3,950'. POH W/E-line. 3. PU Perf Guns, RIH (note Fluid level)and Perforate the A-3 Interval (3,577—3,592). • Note any pressure change at the well head, Open well to separator and flow well for at least 1 hr. Note any flow of gas from the well. Note Fluid Level. If insufficient gas flow (< 1MM) confer with Operations Engineer for decision to proceed to next interval. • Check Fluid level. If a water influx is encountered, a decision will be made to set an additional plug if needed. If no water influx,then move up hole to perforate the next interval. • The progression will be: i. A-6(3,981-3,988) ii. Set a Plug if un productive iii. A-3 (3,577—3,592) iv. SZ23 (3,223—3,240) v. SZ19(2,710-2720) vi. Set a Plug if unproductive vii. SZ13(1,849—1,855) viii. SZ13 (1,826-1,833) ix. Set a plug if unproductive x. SZ11(1,502—1,507) xi. SZ10(1,477—1,482) • Each interval will be flowed for 12 hours to establish if the interval will produce. • Because these are short/shallow intervals with potential for sanding at high rates, hold a choke on the well prior to perforating so that rates do not exceed 2mmcfd from each zone. 4. Schedule test of SSV within 5 days of return to production. SCHEMATIC • Well M-17 Completed: Future Ilii,..,,,.11:1.1.8.,III. a s of 11/30/15 CASING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM(MOrkb) 28" Structural 27 Surface 485' RKB to TBG Head 71.82' 13-3/8" 68 L-80 BTC 12.415 Surface 895' 9-5/8" 40 L-80 BTC 8.835 Surface 1,430' 7" 26 1-80 BTC-M 6.276 Surface 5,700' 1 28"Conductor 5"liner 18 1-80 H513 4.180• 5472' 7,637' ECP stage collar TUBING DETAIL EL 13-3/8"in 17 W'Hole 3-1/2" 9.2 1-80 TC-II 2.992 Surf 1,415' ECP Stage Collar 3-1/2" 9.2 1.80 TC-II 2.992 4,975' 5,098' Est TOC @ 920' `The 5",18#,F1 liner has an ID of 4.276"&a drift of 4.155". The H513 connection has a 4.194"machined pin ID.The Baker ZXP Flex III hanger packer assembly has a TKC x H513 X over with a 4.180"machined ID.This represents the minimum ID in the 5"liner. Top Fish:Debris from 5"drillable bridge plugs. Bottom Fish: 2.5X15'Spiral let El gun,1-11/16"x 1.5 firing head,1-11/16"x 1.5'magnet,1-11/16"x 1'CCL,1-11/16"x 1'swivel,1-11/16" x 18'weight bar,1-3/8-x 2.2'rope socket. 1 2 - ' i.' ' 9-5/8"in 12'/."Hole Jewelry Detail fmr I 3 _ No. Item Depth OD ID Notes 13 3/8 x 28"ECP Stage Collar 454' Cemt'd to Surf 4 ga 9 5/8 x 13 3/8 ECP Stage Collar 849' Attempt to Cemt to ML 1 SSSV 414' 5.375" 2.813" 5 2 GEM 1,362' 5.00" 2.813" SZ Zone 3 Packer 1,390' 5.870" 3.00" A Zone 4 X-Nipple 1,406' 4.50" 2.813" S WLEG 1,415' 4.50" 2.992" lant Top of tubing 6 Production Packer 4,980' 5.97" 3.900" Baker S-3 1>E ti. @4,975' 7 X Profile Nipple w/X-Plug 5,040' 4.50" 2.813" 6 mi, =- 8 WLEG(bottom) 5,098' 3.93" 2.960" 7 r{t4 �ie 9 ZXP Flex III Hanger Packer 5,472' 5.250" 4.180" •Y ((( 10 5"Cement Retainer 7,213' »» »» Top of Cement at 7,200' 8 CS Zone TOC 5,276 C7 Zone ,-4,,,t ! .w Perforation Detail t it, = MD TVD Date Zone (SPF) Notes 1,477'-1,482' 1,446'-1,450' Future SZ 10 9r 7y,.£ 1,502'-1,507' 1,468'-1,472' Future SZ 11 i ..MR 7"Casing in 8 W Hole 1,826'-1,833' 1,747'4,752' Future SZ 13 k'.':'1:;'.:' 1,849'1,855' 1,766'-1,770' Future SZ 13 ^;✓.t 2,710'-2,720' 2,330'-2,336' Future SZ 19 GanZone-0,1,1 Llu,;gt. 3,223'-3,240' 2,618'-2,628' Future SZ 23 3,577'-3,592' 2,853'-2,865' Future A 3 'i,`,;'i:-t 3,981'-3,968' 3,179'-3,185' Future A6 5,147-5,167' 4,189'-4,206' 6/18/2012 C5 6 2.5"x20'60 HC Deg Phase a ' 5,229'-5,236' 4,260'-4,226' 6/15/2012 C7 4 2.5"x7'60 Spiral Strip Deg Phase 5,782'-5,788' 4,740'-4,745' 11/29/2007 6 Squeezed,Ref SCMT Log 11/22/07 '. D4 Zone 5,832'-5,856' 4,784'-4,805' 2/19/2008 D3B 5 Squeezed,112.5 bbls 15.8LXT �+�'; 4 ppg D4 Zone 6,029'-6,042' 4,955'-4,967' 6/1/2012 04 4 2-1/2"Shogun Strip 60 deg Spiral Strip l'.1 4 6,066'-6,073' 4,988-4,994' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip Top of , 4. 1, 06 Zone Primary 6,169'-6,179' 5,078'-5,086' 6/1/2012 D6 4 2-1/2"Shogun Strip 60 deg Spiral Strip Cement 6,234'-6,240' 5,135'-5,140' 11/27/2007 6 Squeezed,Ref SCMT Log 11/22/07 is 7034' ; 014 Zone 7,142'-7,155' 5,919'-5,930' 4/5/2010 014 6 SIB 2-1/2"PJOmega HC60°phasing 7,296'-7,308' 6,052'-6,062' 2/16/2008 0-16A 2-Sep Plugged/Squeezed thru cement retainer at 7213' Top of Cement Plug at 7200' with 3.25 bbls of LXT cement and 2 bbls dumped on /6 ' ' 7,361'-7,391' 6,108'-6,135' 2/13/2008 D-16C 2-Sep ! i u16A Zone(sqzd plugge, top and dressed to 7200' aim! D16C Zone Is°zd olueeer Isolated with 5"Posi-Set Plug at 7423'and 15.25 7,456'-7,470' 6,191'-6,204' 12/21/2008 D-17 11 7 Zone(,!,ggedl gals(18')of dump bailed cement. 5"Cosi-Set plug at 7423'w/15.23 gals cmt placed w/dump bailer(TOC 5"Liner Shoe at 7637' tagged at 7405'ELM,2-11-08) 6-1/8"Hole TD at 7670' MAX HOLE ANGLE: 56.4°@ Tangent 2,796'MD hb.te.Placed 2'of ceramic beads on top of sand fill @ 5,297'. Revised:11/30/15 by JLL • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, November 20, 2015 4:00 PM To: 'Ted Kramer';Trudi Hallett; Regg,James B (DOA) Cc: Stan Golis;Juanita Lovett; Daniel Duckworth - (C) Subject: RE: M-17 stuck RHC Sundry#315-523, PTD 207-120 Ted, If SL operations are not successful in getting RHCP plug body out of the wellbore then you have approval to proceed as shown below. You may operate under the current sundry 315-523 to pull the completion and rerun (with mechanical set packer this run). Make sure you update the MOC form. Good luck with getting RHCP plug out. Hopefully you can get that accomplished with just Slickline swaging the tight spot. Regards, 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: Friday, November 20, 2015 2:26 PM To: Schwartz, Guy L(DOA); Trudi Hallett; Regg, James B (DOA) Cc: Stan Golis; Juanita Lovett; Daniel Duckworth - (C) Subject: RE: M-17 Sundry #315-523, PTD 207-120 Guy, Here is what transpired on the M-17 and the plan forward: We had placed an RHCP plug in the X nipple below the packer prior to it being ran in the well. The purpose of the plug is to pressure up against it in order to set the packer. The packer was set without issues. We recovered the bar, and then ran in and latched onto the plug. The plug came free and pulled fine until we got to the hanger. At that point we could not get through the 10'pup under the tubing hanger. We then decided to push the plug back to bottom and either force it out the tubing or cut off the x nipple and let it fall to bottom. We pushed the plug down clear of the pup joint but the plug would not pass through the seat nipple on top of the SSSV. I discussed this with Pollard Wireline and determined that the reason the plug will not go down is because there is a collar that when depressed causes some dog ears to push out. That is what is hanging up in the top of the SSSV Seat. 1 • • I then asked the rig to run a GR down elow the hanger to ensure that we could still drift. That is when we found that the problem was not in the tubing hanger but in the 10' pup below the hanger. It is believed to be an overtightened collar that has reduced the ID enough to not let the plug pass. Plan forward: 1.) We are currently Mobilizing Slickline equipment to see if the collar can be opened up enough to remove the plug. 2.) If that is unsuccessful,we will rig back up on the well. 3.) ND WH, NU BOP and Test to250 psi low, 2,500 psi high. ( A request to witness BOP's has been sent in to AOGCC). 4.) Unseat the tubing hanger, unset the retrievable packer(straight pull), and pull current completion out of the well. 5.) PU new packer(mechanical set), GLM, Rebuilt Baker SSSV on 3-1/2" 9.2#TCII tubing and RIH. 6.) Place packer on depth at+/- 1,400'. 7.) Set packer with 1/2 turn rotation at the packer. 8.) Pressure test IA to 1,500 psi on chart for 30 min. Release pressure. 9.) ND BOP, NU Well head and test wellhead to 5,000 psi. 10.)RDMO rig 404. Please let me know if this meets with the your approval and if a change in program needs to be filed. Sincerely, Ted Kramer Senior Operations Engineer Hilcorp Alaska LLC 907-777-8420(Office) 985-867-0665 (cell) From: Schwartz, Guy L (DOA) [mailto:cm,schwartz©alaska.gov] Sent: Friday, November 20, 2015 11:49 AM To: Trudi Hallett; Regg, James B (DOA) Cc: Ted Kramer; Stan Golis; Juanita Lovett; Daniel Duckworth - (C) Subject: RE: M-17 Sundry #315-523, PTD 207-120 Truth, I understand the new completion needs to be pulled due to a PX plug being hung up in SSSV. Will need a updated work description from you on what you are planning on doing to repair well. Current well status is not perfed as I understand and should be isolated from the reservoir. I am not sure if a sundry will be required to reenter the well but will make that call after I hear from you. Regards, Guy Schwartz Sr. Petroleum Engineer 2 • • 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(Guv.schwartz@alaska.gov). From: Trudi Hallett [mailto:thallett©hilcorp.com] Sent: Thursday, November 19, 2015 11:10 AM To: Schwartz, Guy L (DOA) Cc: Ted Kramer; Stan Golis; Juanita Lovett; Daniel Duckworth - (C) Subject: RE: M-17 Sundry #315-523, PTD 207-120 Hello,Guy- Please find the attached perf request for the M-17.Our plan is to perf and test each zone as we march up the wellbore. I have attached the approved sundry and the CBL for your convenience.We wanted to give you the heads up before we proceed. Thank you!! TruSii Trudi Hallett Operations Engineer Cook Inlet Offshore Asset Beam Ililcorp Alaska LLC Hilcorp A Company Built on Energy thallett@hilcorp.com 0: 907.777.8323 C: 907.301.6657 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz(talaska.gov] Sent: Tuesday, November 17, 2015 2:33 PM To: Ted Kramer Subject: RE: M-17 Sundry #315-523, PTD 207-120 Ted, After review of the attached CBL log I agree with your assessment of cement coverage.AOGCC will grant a variance to 20 AAC 25.030(d)(5)which requires 500 ft of cement above significant hydrocarbon zones.The CBL shows plenty of good cement isolation (+350 ft) between 1000' and the top interval at 1477 ft md. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 3 • • 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:tkramerCa�hilcorp.com] Sent: Tuesday, November 17, 2015 2:22 PM To: Schwartz, Guy L(DOA) Subject: M-17 Sundry #315-523, PTD 207-120 Guy, Hilcorp is asking for a variance from the 500'of isolation for perforating the M-17 well.The cement bond log attached shows that we have 370 ft of isolation from the top planned perforation (1477'+1-and the surface.The intervals I counted as isolation are as follows: 1050—1120 1170—1200 1200—1240 1250—1480 370'total Please let me know if this is acceptable to the AOGCC. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 4 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, November 05, 2015 10:34 AM To: 'Ted Kramer' Cc: Juanita Lovett; Stan Golis Subject: RE: M-17 RWO to move Packer up hole - Sundry# 315-523 PTD #207-120 Ted, Sundry 315-523 is approved with the latest clarification information below. Forward me results of the CBL when you have them ... if perf intervals change significantly a new sundry may be needed. Guy Schwartz SCAtiaED MAY 1 1 516 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, November 02, 2015 2:24 PM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett; Stan Golis Subject: Re: M-17 RWO to move Packer up hole - Sundry # 315-523 PTD # 207-120 Guy, This Email is a follow up to our phone conversation today regarding more fluid information on the Sundry on the above well. The well control for M-17 will consist of killing the well with FIW prior to setting the BPV and ND Tree, NU BOP. FIW is more than adequate to control the depleted gas zones in this well. We will continue to add FIW as needed until we rig up Slick Line and set the plug in the X-profile in step#3. At this time,there will be two barriers (the plug and the FIW on top of the plug). Steps 4 through 7 are e-line operations which we will know running in where the fluid level is and if the well remains stagnate (pressure wise). Step#12 involves setting the new packer which we will pressure test to 1,500 psi . Step# 13 is ND Bop's and NU Wellhead and test the tree. The tree will be pressure tested to its rated pressure of 5,000 psi. The new perf interval will be selected based on the GR and CBL logs, and will be shot on E-line after the rig is de-mobed 1 • P4ease let me know if there is anything else you require. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 2 • 4i<OF T�f I�7 s� THE STATE Alaska Oil and Gas �� °f Conservation Commission LAsKA 333 West Seventh Avenue r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ALAS1'P Main: 907 279 1433 SCANNEV Fax• 907.276 7542 www.aogcc.alaska.gov Ted Kramer Sr. Operations Engineer p7 r a a Hilcorp Alaska, LLC / 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 95503 Re: McArthur River Field, Middle Kenai Gas Pool, TBU M-17 Sundry Number: 315-523 Dear Mr. Kramer: 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, 1P44'4•L Cathy P oerster Chair 94— DATED this 31y of August, 2015 Encl. RBDM S€P Q2 20t • RECEIVED STATE OF ALASKA AUG 2 6 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION Ell 3 ( I 1 s APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request Abandon❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Suspend❑ Perforate 0 Other Stimulate Alter Casing ❑ Change Approved Program ❑ Plug for Rednll El Perforate New Pool ❑ Repair Well 1 1 Re-enter Susp Well ❑ Other: Complete 0 2.Operator Name 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC ' Exploratory ❑ Development 0 , 207-120 3 Address 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20552-00 7 If perforating / 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 228A Will planned perforations require a spacing exception? Yes ❑ No El / Trading Bay Unit M-17 9 Property Designation(Lease Number): 10 Field/Pool(s): ADL0017594/ADL0018730 ' McArthur River Field/Middle Kenai Gas Pool • 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) . 7,670 . 6,380 0 5,276 . 4,301 7,200 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 485' 28" 485' 484' Surface 895' 13-3/8" 895' 894' 5,020 psi 2,260 psi Intermediate 1,430' 9-5/8" 1,430' 1,403' 5,750 psi 3,090 psi Production 5,700' 7" 5,700' 4,669' 7,240 psi 5,410 psi Liner 2,165' 5" 7,637' 6,350' - 8,290 psi 7,250 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade. Tubing MD(ft) 5,147-5,236 4,189-4,226 3-1/2" 9 2#/L-80 5,098 Packers and SSSV Type. Packers and SSSV MD(ft)and ND(ft) Baker S-3/ZXP/Flex III Hanger Packer&Baker T-5 SSSV 4,980'(MD)4,043'(ND)/5,472'(MD)4,471'(ND)&426'(MD)426'(ND) 12 Attachments Description Summary of Proposal 0 13.Well Class after proposed work Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic El .tvelopment El Service ❑ 14.Estimated Date for 15.Well Status after proposed work Commencing Operations 9/10/2015 OIL El WINJ ❑ WDSF❑ Suspended ❑ 16 Verbal Approval: Date GAS El WAG ❑ GSTOD SPLUG ❑ Commission Representative GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer 1 Email tkramer@hilcorp.com Printed Name Ted Kramer Title Sr Operations Engineer �� Signature ./1.-----t-----‘ �-----t-----‘ Phone (907)777-8420 Date 8/26/2015 COMMISSION USE ONLY Conditions of approval Notify Commission�so that a representative may witness Sundry Number I n Plug Integrity ❑ BOP Test (]I( Mechanical Integrity Test ❑ Location Clearance ❑ Other. r .- .2 5-0'v A5z.. fior —7------4- C 4,1,e -p , 1/6o "SG) Spacing Exception Required? Yes ❑ No (1J Subsequent Form Required: /© - 41 01-"' C Approved by COMMISSIONER THE COMMISSIONAPPROVEDBY �—S / _ Date J O RGINALfm 04.//s- ii '7;0,- / 1221 7/—S---' Submit Form and Firm 1n-dnaRamcarl 5/9015 Annrnvad annlicatinn is valid fnr 12 months frnm tha data of annrnvaL �....,.�.............r,......,...... Well Work Prognosis Well: M-17 Hilcarp Alaska,LLC Date: 08/26/15 Well Name: Trading Bay Unit M-17 API Number: 50-733-20552-00 Current Status: Gas Well Leg: A-1 (West) Estimated Start Date: 09/10/15 Rig: Moncla 404 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 207-120 First Call Engineer: Ted Kramer Office: 907-777-8420 Cell: 985-867-0665 Second Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Current Bottom Hole Pressure: 141 Psi SI Tubing Pressure Maximum Expected BHP: 1,500 psi (Based on normally pressured intervals) Max.Allowable Surface Pressure: 1,160 psi. (Based on a 0.1 psi pressure gradient). Brief Well Summary M-17 was re-completed to the C-5 and C-7 pay intervals in June of 2012. Since that time gas production has declined to 500 mcfd at 65 psi flowing surface pressure. The work plan for well is to set a plug in the X Nipple @ 5,040'. Cut the tubing above the packer and pull the existing tubing. Run CBL to confirm cement isolation. PU a new packer,GLM, and SSSV and RIH setting packer at 1,395'+/-. Procedure: (Note: Since this is a gas well,the workover package for this well program will be the full package including pits, tanks and we will be utilizing the choke manifold.) 1. Skid and RU Rig 404 over M-17 well slot. �`v( 2. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 2,500 psi HIGH. 3. RU SL, PU X-plug, RIH and set in X-profile at 5,040'. RD SL. — p; -' 4 s'41`)p ' "' P 4. RU E-Line. PU and RIH with Jet Cutter, Log on depth,cut tubing @ 4,97 '. POOH with Cutter, RD E-line. 5. POOH with Production Tubing. 6. RU E-line, PU CBL and RIH to 4350'. POH Logging 7" casing up to '. Evaluate CBL. (Note: Drilling file indicates that cement was circulated to surface on the 9-5/8" casing string.) If CBL shows good cement isolation behind pipe,go to step 12. Otherwise go to step 8. Got-') PU RBP, RIH to 4960' and set. Dump 20'of sand on top of RBP. 9 PU Perf guns on E-line and RIH and perforate to perform an appropriate block squeeze according to the CBL results. (Note:The block squeeze will be discussed with AOGCC once guidance of the CBL is known.) WOC. PU RIH with bit and drill out cement and pressure test. . PU retrieving tool, RIH and wash sand and retrieve RBP. POOH with same. 2. PU Packer, GLM, and SSSV, RIH setting Packer at+/- 1,395'. Well Work Prognosis Well: M-17 Hilcorp Alaska,LLC Date: 08/26/15 13. ND BOP, NU wellhead and test. 14. RU E-line. RIH with Perf guns and perforate according to the Final Approved Perforation Request Form. 15. Turn well over to production 16. Schedule test of SSV within 5 days of return to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Current Wellhead Diagram/New Wellhead Diagram(Same) SHP Well M-17 As Completed 4/5/10 'Blear')Alaska,LLC SCHEMATIC As PB'd/Perfed 6/1/12 CASING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM(MDrkb) 28" Structural 27 Surface 485' RKB to TBG Head 71.82' 13-3/8" 68 L-80 BTC 12.415 Surface 895' 9-5/8" 40 L-80 BTC 8.835 Surface 1,430' I I 7" 26 L-80 BTC-M 6.276 Surface 5,700' 5"liner 18 L-80 H513 4.180' 5472' 7,637' 28"Conductor ECP Stage Collar ' - (tube)2.992 1 13-3/8"in 17'A"Hole 3-1/2" 9.2 L-80 TC-II (TUBINGconnectioDETAILn)2.980 Surface 5,098' I i (drift)2.867 1 II ECP Stage Collar "The 5",188,Fl liner has an ID of 4.276"&a drift of 4.155". The H513 connection has a 4.194"machined pin ID.The Baker ZXP Flex III hanger packer assembly has a TKC x 11513 X over with a 4.180"machined ID.This represents the minimum ID in the 5"liner. Top Fish: Debris from 5"drillable bridge plugs. Est TOC @ 920' Bottom Fish: 2.5X15'Spiral Jet EJ gun,1-11/16"x 1.5 firing head,1-11/16"x 1.5'magnet,1-11/16"x 1'CCL,1-11/16"x 1'swivel,1-11/16" x 18'weight bar,1-3/8"x 22'rope socket. Perforation Detail MD TVD Date Zone (SPF) Notes 9-5/8"in 12 h"Hole 5,147'-5,167' 4,186-4,206' 6/18/2012 C5 6 2.5"x20'60 HC Deg Phase 5,229'-5,236' 4,260'-4,226' 6/15/2012 C7 4 2.5"x7'60 Spiral Strip Deg Phase 5,782'-5,788' 4,740'-4,745' 11/29/2007 6 Squeezed,Ref SCMT Log 11/22/07 5,832'-5,856' 4,754'-4,505' 2/19/2008 D3B 5 Squeezed,112.5 bbls 15.8 ppg LXT 6,026-6,042' 4,955'-4,967' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip . . 6,066-6,073' 4,988-4,994' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip 6,169'-6,179' 5,078'-5,086' 6/1/2012 06 4 2-1/2"Shogun Strip 60 deg Spiral Strip ���jj`,, 6,234'-6,240' _ 5,135'-5,140' 11/27/2007 6 Squeezed,Ref SCMT Log 11/22/07 `�b� 7,142'-7,155' 5,919'-5,930' 4/5/2010 014 6 SLB 2-1/2"PJ Omega HC 60°phasing 7,296-7,308',P1 6,052'-6,062' 2/16/2008 D-16A 2-Sep Plugged/Squeezed thru cement retainer at 7213' I l t t with 3.25 bbls of LXT cement and 2 bbls dumped 6 _ 7,361'-7,391' 6,108'-6,135' 2/13/2008 D-16C 2-Sep on top and dressed to 7200' 7,456-7,470'lili- 0"1 6,191'-6,204' 12/21/2008 D-17 11 Isolated with 5"Posi-Set Plug at 7423'and 15.25 gals(18')of dump bailed cement. 8 C5 Zone Jewelry Detail Toc 5,276 C7 Zone No. Item Depth OD ID Notes _ 13 3/8 x 28"ECP Stage Collar 454' Cemt'd to Surf 9 5/8 x 13 3/8 ECP Stage Collar 849' Attempt to Cemt to ML 1 SCSSV 426' 5.380" 2.813" Baker TE-5 2 GLM 4 1,539' 5.968" 2.867" SFO-2 9 3 GLM 3 3,192' 5.968" 2.867" SFO-2 7"Casing In 814"Hole 4 GLM 2 4,245' 5.968" 2.867" SFO-2 5 GLM 1 4,914' 5.968" 2.867" SFO-2 6 Production Packer 4,980' 5.97" 3.900" Baker S-3 D3B Zone(sqzd plugged) 7 X Profile Nipple 5,040' 4.50" 2.813" .• I 8 WLEG(bottom) 5,098' 3.93" 2.960" 9 ZXP Flex III Hanger Packer 5,472' 5.250" 4.180" 10 5"Cement Retainer 7,213' »» »» Top of Cement at 7,200' • 1 Dens Yield ,i Cementing Information D4Zorro Description Volume (ppg) (ft3/sx) Notes = D4 Zone 13-3/8"Stage 1 147 15.8 1.16 G GasBlok Top of — D6 Zone 13-3/8"Stage 2 76 L,188 T 15.8 1.17 62 bbls Cement to Surf,G GasBok and G CaCI Primary 9-5/8"Stage 1 57 15.8 1.16 G GasBlok Cement - 4.09-5/8"Stage 2 32 15.8 1.17 G GasBlok,Cmt to surf is 7034' 7"Production 143 12 2.49 G LiteCrete d'''"-- D14 Zone G LXT,Partial to complete losses,packed off. 5"Liner Primary 49.5 15.8 1.2 TOC @ 7034'per SCMT Top of Cement Plug at 7200' 10 ' :P� 5"Circ.Sqz.6240'-5782' 16.5 15.8 1.2 G LXT,Partial to complete losses. D16A Zone(sqzd plugged) 5"Balanced Plug across I 21 15.8 1.21 G LXT,Partial returns,plug was ineffective D16C Zone(scud olueeedl D3B and old Sqz Perfs 5"Sqz Plug across D3B (1"plug)45 bbls G LXT,down sqz thru cmt.ret.,1'plug broke D17 Zone(plugged) d 15.8 1.21 down at 1150 psi,2nd plug held hydrostatic (2 plug jobs) (2" plug)46.5 bbls allIMI 5"Posi-Set plug at 7423'w/15.23 gals column,no surface pressure test cmt placed w/dump bailer(TOC 5"Downsqz thru cmt. 5"Liner Shoe at 7637' tagged at 7405'ELM,2-11-081 retainer for D16A and 3.25 15.3 1.21 G LXT,down sqz thru cmt.ret. 6-1/8"Hole TD at 7670' D16C 5"Cmt.Plug on top of retainer above D16A and 2 15.3 1.21 G LXT,dumped 2 bbls on top of retainer and MAX HOLE ANGLE: 016C polished to 7200' 56.4°@ Tangent 2,796'MD Note:Placed 2'of ceramic beads on top of sand fill @ 5,297'. Well retail Revised:7/16/2012 by TDF SHP Well M-17 Completed: Future Hilcorp Alaska,LLC PROPOSED CASING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM(MDrkb) 28" Structural 27 Surface 485' RKB to TBG Head 71.82' 13-3/8" 68 _ L-80 BTC 12.415 Surface 895' 4 1 i 9-5/8" 40 L-80 BTC 8.835 _ Surface 1,430' 4 7" 26 L-80 BTC-M 6.276 Surface 5,700' 1 28".C.onductor 5"liner 18 L-80 H513 4.150" 5472' 7,637' ECP Stage Collar TUBING DETAIL 13-3/8"in 17 W'Hole 3-1/2" 9.2 L-80 TC-II 2.992 Surf ±1,425' 1 /* ECP Stage Collar *The 5",188,FJ liner has an ID of 4.276"&a drift of 4.155". The H513 connection has a 4.194"machined pin ID.The Baker ZXP Flex III hanger packer assembly has a TKC x H513 X over with a 4.180"machined ID.This represents the minimum ID in the 5"liner. Top Fish:Debris from 5"drillable bridge plugs. Est TOC @ 920' 2 Bottom Fish: 2.5X15'Spiral Jet EJ gun,1-11/16"x 1.5 firing head,1-11/16"x 1.5'magnet,1-11/16"x 1'CCL,1-11/16"x 1'swivel,1-11/16" x 18'weight bar,1-3/8"x 22'rope socket. I , 9-5/8"in 12''4"Hole Jewelry Detail 3 1 I _ No. Item Depth OD ID Notes _ 13 3/8 x 28"ECP Stage Collar 454' Cemt'd to Surf 4 9 5/8 x 13 3/8 ECP Stage Collar 849' Attempt to Cemt to ML 1 SSSV ±425' 5 2 GLM ±1,385' SZ Zone 3 Packer ±1,395' 4 X-Nipple ±1,415' A Zone 5 WLEG ±1,425' 6 Production Packer 4,980' 5.97" 3.900" Baker S-3 11Bfk'.I 7 X Profile Nipple w/X-Plug ±5,040' 4.50" 2.813" 6 - = II8 - ,p 8 WLEG(bottom) 5,098' 3.93" 2.960" 7 -*�' f t7 9 ZXP Flex III Hanger Packer 5,472' 5.250" 4.180" _ 10 5"Cement Retainer 7,213' »» »» Top of Cement at 7,200' 8 - C5 Zone TOC 5,276 - C7 Zone . ', Perforation Detail Ap. W MD TVD Date Zone (SPF) Notes 1., 1,477'-1,482' 1,446'-1,450' Future SZ 10 1,502'-1,507' 1,468'-1,472' Future SZ 11 lii 7"Casing in 8i4"Hole 1,826'-1,833' 1,747'-1,752' Future SZ 13 I 1,849'-1,855' 1,766-1,770' Future SZ 13 2,710'-2,720' 2,330'-2,336' Future SZ 19 D3B Zone(sqzd plugged) 3,223'-3,240' 2,618'-2,628' Future SZ 23 3,577'-3,592' 2,853'-2,865' Future A 3 3,981'-3,988' 3,179'-3,185' Future A6 5,147'-5,167' 4,189'-4,206' 6/18/2012 C5 6 2.5"x20'60 FIC Deg Phase 5,229'-5,236' 4,260'-4,226' 6/15/2012 C7 4 2.5"x7'60 Spiral Strip Deg Phase 5,782'-5,788' 4,740'-4,745' 11/29/2007 6 Squeezed,Ref SCMT Log 11/22/07 4 D4 Zone 5,832'-5,856' 4,784'-4,805' 2/19/2008 D3B 5 Squeezed,112.5 bbls 15.8 ppg LXT D4 Zone 6,029'-6,042' 4,955'-4,967' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip Top of `= D6 Zone 6,066-6,073' 4,988-4,994' 6/1/2012 D4 4 2-1/2"Shogun Strip 60 deg Spiral Strip Primary6,169'-6,179' 5,078'-5,086' 6/1/2012 D6 4 2-1/2"Shogun Strip 60 deg Spiral Strip Cement _ 6,234'-6,240' 5,135'-5,140' 11/27/2007 6 Squeezed,Ref SCMT Log 11/22/07 is 7034' = D14 Zone 7,142'-7,155' 5,919'-5,930' 4/5/2010 014 6 SLB 2-1/2"Pi Omega HC 60°phasing 7,296-7,308' 6,052'-6,062' 2/16/2008 D-16A 2-Sep Plugged/Squeezed thru cement retainer at 7213' to --i._5°` Top of Cement Plug at 7200' with 3.25 bbls of LXT cement and 2 bbls dumped on 7.361'-7,391' 6,108'-6,135' 2/13/2008 D-16C 2-Sep i 016A Zone(sqzd plugged) top and dressed to 7200' Boa.' 116C Zone isozd xloeeedi Isolated with 5"Posi-Set Plug at 7423'and 15.25 7,45V-7,470' 6,19V-6,204' 12/21/2008 D-17 11 gals(18')of dump bailed cement. OA. ii J17 Zone(plugged) dellbk 5"Posi-Set plug at 7423'w/15.23 gals cmt placed w/dump bailer(TOC 5"Liner Shoe at 7637' tagged at 7405'ELM,2-11-08) 6-1/8"Hole TD at 7670' MAX HOLE ANGLE: 56.4°@ Tangent 2,796'MD Note:Placed 2'of ceramic beads on top of sand fill @ 5,297'. Revised:08/26/15 by JLL PLATFORM STEELHEAD 17 ./ 26 X 13-3/8"X 9-5/8"X , X 3-1/2"OD, 5,000 MSPIMB-220 MULTIBOWL ASSY • SP-5750 fi. t -1... .. 1I 3-1315M rii MAW • „.. IOW .11•10.) • �• 3-1M 5M U d •Srm �.�j —131144919 8401•91 .._.. - 1�•�= m1MM1011101rlT r 9•410.1111•ENNEW .. Mt/MUM SIM•G MOCCI Wx. STEN/ 26.50' i 1112 XT _ T T nu1•9 wNc1a 1$1•X1 .__ ..._ --.... .1710 X1 • 1919,9499499919•339-Hamm fN01 GRIM 19.•NNEWE _ 1 OM 121.00¢10•011121.00¢10•0121.00¢10•011C.6.1000 .M0XX1M 1f!4X7 11/1[119iJ1C'MOXIFF �' •�-p;' 1•'.e l )I •4.-1 �i '� 1$lQX9 • t •91 _ .._ �S 1111• MOOT 1111•19•9 cum WWII= 1010913/MICnSNr g1•X•M�- IM1 l00.OWM 27.50' -_I116 I_ Irmor sea RTJ } r 24.50' 1 - 6”6 � - - VIEW - - 6"600 RT.]OUTLETS j ©30 DEGFPES { WELLHEAD ROOM FLOOR 28'CASINO 3-3W 13'W CAMH 7 ..___..959 CASING —._ — 3X'00 T191H0 • Vetco Gray 7Qel nelegy ai fOesAk vetco Steelhead Platform M-17 BOP Moncla 404 08/25/2015 IliIriu-p.Alaikn,I.1.1. 401 O ffn n rain rft t, 3/4' Shaffer 13 5/8 5M t t rf t rtfirtfi rf Iplill III 1!I I I Variable 2 7/8-5 ' CI® 01, b - ,_ 4.67' Blind Rams °� � 13 5/8-5000 1 •I H III I11 I/1111 III it 4 111 Itl ill :: ! iv 17 ILLrfiqi J, 0 :a2.00'- • III III I connections for hoses III 1111111 II 111 1.58' Dr,Deco Riser,13 5/8 5M API hub X 13 5/8 5M FE 18.83' ei Riser,13 5/8 5M FE X 135/8 5M API hub i�.00 I I t I II Moncla Rig 404 BOP Test Procedure Attachment#1 Il ilrorp Alaska,LId; Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test)joint to lift-threads d) For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure Moncla Rig 404 BOP Test Procedure Hilrorp Alaska.L, Attachment#1 .c c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile /penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt.of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. Moncla Rig 404 BOP Test Procedure Hilrorp;Ua..ka, Attachment#1 d) Open C-1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high,for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test,open same. ii) Valves, 3,4,9. After test, open valves 3 &4. Leave 9 closed. iii) Valves 5, 6, 9. After test,open valves 5 & 6, leave 9 closed. iv) Valves, 7,8,9. After test,open all valves. e) Close C-2. This is the HCR(the hydraulic controlled remote)valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K-1, K-2, and K-3 on the kill (pump-in) side by pressuring up on tubing.Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/- 3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. • • . 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. c Q 17 - La © Well History File Identifier Organizing (done) ❑ Two -sided 1111111111111111111 ❑ Rescan Needed 11111111111 111(111 R CAN DIGITAL DATA OVERSIZED (Scannable) Color 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: Alb Date: Z a Si /s/ MP Project Proofing I BY: Date: D g , /s/ m P __ Scanning Preparation x 30 = / O + (a.7 = TOTAL PAGES 17 7 (Count does not include cover sheet) BY: Maria Date: O 1/ /s/ Production Scanning III 111111111111111 d Stage 1 Page Count from Scanned File: j 7 U (Count does include cover eet) Page Count Matches Number in Scanning Pre aration: YES NO BY: Date: 3 f I /s/ (yip Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I ReScanned 1 BY: Maria Date: /s/ Comments about this file: Quality Checked 1111111 111 Ill 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA • • A KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate 0 Other ❑ Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extensiorn❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WellI❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 207-120 a 3. Address: 3800 Centerpoint Drive, STE 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20552 -00 7. Property Designation (Lease Number): 8. Well Name and Number: E' VED ADL0017594 / ADL0018730 Trading Bay Unit / M -17 '� 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): JUL 16 2012 MacArthur River / Middle Kenai Gas Pool 11. Present Well Condition Summary: /il OGC Total Depth measured 7,670 feet Plugs measured 7,104 feet (V' true vertical 6,380 feet Junk measured N/A feet Effective Depth measured 7,104 feet true vertical 5,886 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 485' 28" 485' 484' Surface 895' 13 -3/8" 895' 894' 5,020 psi 2,260 psi Intermediate 1,430' 9 -5/8" 1,430' 1,403' 5,750 psi 3,090 psi Production 5,700' 7" 5,700' 4,669' 7,240 psi 5,410 psi Liner 2,165' 5" 7,637' 6,350' 8,290 psi 7,250 psi Liner Perforation depth Measured depth 7,073 -7,079 feet True Vertical depth 5,860 -5,865 feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2# L -80 5,098' (MD) 4,146' (TVD) Baker S -3/ ZXP 4,980' (MD), 4,043' (TVD) Packers and SSSV (type, measured and true vertical depth) Flex III Hanger 5,472' (MD), 4,471' (TVD) Baker T -5 426' (MD), 425' (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): ArMitiED JUL 1 8 Z 01 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: 0 573 0 70 133 Subsequent to operation: 0 3,069 0 415 376 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development O Service ❑ Stratigraphic ❑ Daily Report of Well Operations 16. Well Status after work: Oil ❑ Gas 5 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: Contact Ted E. Kramer Printed Name Ted E. Kramer Title Operations Engineer Signature 1 Phone 907 - 777 -8420 Date 7/16/2012 RBDMS JUL 17 2012 f7-ieo-/- Form 10 -404 Revised 11/2011 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M -17 507332055200 207 -120 6/1/12 6/2/12 Daily Operations: 06/02/12 - Saturday RU and pressure test lubricator to 250 psi low and 3,000 psi high. RIH w/2.72" gauge ring, tie into SLB SCMT /GR /CCL /Temp Press tool dated 11 -22 -2007. Tagged fill at 6,397'. POOH. RIH w/2 -1/2 "x10' Spiral Strip, 4 spf, 60 deg pert gun. Tagged fill at 6,397'. Spot gun from 6,169' to 6.179- Lper Final Approved Perforation Request Form dated 25 -May- 12 and fired gun. POOH. RIH w/2- 1/2 "x7' Spiral Strip, 4 spf, 60 deg phase perf gun. Soot gun from 6,066' to 6,073' and fired gun. POOH. All shots fired. RIH w/2 -1/2 "x13' Spiral Strip, 4 spf, 60 deg phase perf gun. Spot elan from 6,029' to 6,042' and fired gun. POOH. All shots fired. Rig down and turn well over to production. • • Steelhead Platform Well M -17 Hilcorp Alaska, LLC SCHEMATIC Recom pleted 4/5/2010 CASING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM (MDrkb) 28" Structural 27 Surface 485' RKB to TBG Head 71.82' 13 -3/8" 68 L -80 BTC 12.415 Surface 895' 9 -5/8" 40 L -80 BTC 8.835 Surface 1,430' 26 L -80 BTC -M 6.276 Surface 5,700' k' 5" liner 18 L-80 H513 4.180' 5472' 7,637' 28" Conductor TUBING DETAIL ECP Stage Collar (tube) 2.992 1 13 -3/8" in 17'A" Hole 3 -1/2" 9.2 L -80 TC -II (connection) 2.980 Surface 5,098' (drift) 2.867 ECP Stage Collar *The 5 ", 186, FJ liner has an ID of 4.276" & a drift of 4.155 ". The H513 connection has a 4.194" machined pin ID. The Baker ZXP Flex 111 hanger packer assembly has a TKC x H513 X over with a 4.180" machined ID. This represents the minimum ID in the 5" liner. Top Fish: Debris from 5" drillable bridge plugs. Est TOC @ 920' Bottom Fish: 2.5X15' Spiral Jet EJ gun, 1- 11/16" x 1.5 firing head, 1- 11/16" x 1.5' magnet, 1- 11/16" x 1' CCL, 1- 11/16" x 1' swivel, 1- 11/16" . H x 18' weight bar, 1 -3/8" x 22' rope socket. Perforation Detail L , MD TVD Date Zone (SPF) Notes 9 -5 /8" in 12'/." Hole 5,147'- 5,167' 4,189'- 4,206' 6/18/2012 C5 6 2.5 "x20' 60 HC Deg Phase 5,229' - 5,236' 4,260' - 4,226' 6/15/2012 C7 4 2.5 "x7' 60 Spiral Strip Deg Phase 5,782' - 5,788' 4,740'- 4,745' 11/29/2007 6 Squeezed, Ref SCMT Log 11/22/07 5,832'- 5,856' 4,784' - 4,805' 2/19/2008 D3B 5 Squeezed, 112.5 bbls 15.8 ppg LXT I 6,029'- 6,042' 4,955' - 4,967' 6/1/2012 `v D4 4 2 -1/2" Shogun Strip 60 deg Spiral Strip 6,066'- 6,073' 4,988 - 4,994' 6/1/2012 .„/ D4 4 2 -1/2" Shogun Strip 60 deg Spiral Strip 6,169'- 6,179' 5,078'- 5,086' 6/1/2012 ✓ D6 4 2 -1/2" Shogun Strip 60 deg Spiral Strip 6,234'- 6,240' 5,135'- 5,140' 11/27/2007 6 Squeezed, Ref SCMT Log 11/22/07 7,142'- 7,155' 5,919'- 5,930' 4/5/2010 D1.4 6 SLB 2 -1/2" PJ Omega HC 60 phasing 7,296'- 7,308' 6,052'- 6,062' 2/16/2008 D -16A 2 -Sep Plugged /Squeezed thru cement retainer at 7213' r egg tom. r with 3.25 bbls of LXT cement and 2 bbls dumped 6 7,361'- 7,391' 6,108'- 6,135' 2/13/2008 D -16C 2 -Sep on top and dressed to 7200' 7,456'- 7,470' 6,191'- 6,204' 12/21/2008 D -17 11 Isolated with 5" Posi -Set Plug at 7423' and 15.25 7 ' gals (18') of dump bailed cement. 8 C5 Zone Jewelry Detail T005276 C7 Zone No. Item Depth OD ID Notes 133 /8 x 28" ECP Stage Collar 454' Cemt'd to Surf r r g y, � ° � *a 9 5/8 x 13 3/8 ECP Stage Collar 849' Attempt to Cemt to ML 1 SCSSV 426' 5.380" 2.813" Baker TE -5 ` ` - 2 GLM 4 1,539' 5.968" 2.867" SFO -2 9 a 3 GLM 3 3,192' 5.968" 2.867" SFO -2 7" Casing in 8 `/a" Hole 141‘2,21.1 4 GLM 2 4,245' 5.968" 2.867" SFO -2 5 GLM 1 4,914' 5.968" 2.867" SFO -2 6 Production Packer 4,980' 5.97" 3.900" Baker S -3 D3B Zone (sqzd plugged) f °° 7 X Profile Nipple 5,040' 4.50" 2.813" Y 8 WLEG (bottom) 5,098' 3.93" 2.960" ' ; #} 9 ZXP Flex 111 Hanger Packer 5,472' 5.250" 4.180" i ti 10 5" Ce Retainer 7,213' »» »» Top of Cement at 7,200' Cementing Information Da zone Description Volume ( (f %s Notes " D4 Zone 13 -3/S" Stage 1 147 15.8 1.16 G GasBlok 13 -3/8" Stage 2 76 L, 188 T 15.8 1.17 62 bbls Cement to Surf, G GasBok and G CaCI Top of it 4 D6 Zone Primary 11' 9 -5 /8" Stage 1 57 15.8 1.16 G GasBlok Cement '''i 9-5/8" Stage 2 32 15.8 1.17 G GasBlok, Cmt to surf is 7034' 4.!. 7" Production 143 12 2.49 G LiteCrete t .a D14 Zone < ' +,) 5" Liner Primary 49.5 15.8 1.2 G LXT, Partial to complete losses, packed off. Top of Cement Plug at 720 TOC @ 7034' per SCMT 0' 10 5" Circ. Sqz. 6240'-5782' 16.5 15.8 1.2 G LXT, Partial to complete losses. - D16A Zone (sgzd plugged) 5" Balanced Plug across I zi - ---- D16C Zone Isazd olueeed) D3B and old Sqz Perfs 21 15.8 1.21 G LXT, Partial returns, plug was ineffective 5" Sqz Plug across D3B (1" plug) 45 bbls G LXT, down sqz thru cmt. ret., 1" plug broke D17 Zone (plugged) 15.8 1.21 down at 1150 psi, 2 " plug held hydrostatic (2 plug jobs) (2" plug) 46.5 bbls column, no surface pressure test 5" Posi -Set plug at 7423' w/ 15.23 gals cmt placed w/ dump bailer )TOC 5" Downsqz thru cmt. 5" Liner Shoe at 7637' tagged at 7405' ELM, 2 - 11 - 08) retainer for D16A and 3.25 15.3 1.21 G LXT, down sqz thru cmt. ret. 6-1/8" Hole TD at 7670' D16C 5" Cmt. Plug on top of G LXT, dumped 2 MAX HOLE ANGLE: retainer above D16A and 2 15.3 1.21 polished to7 00'bbls on top of retainer and 56.4 @ Tangent 2,796' MD Note: Placed 2' of ceramic beads on top of sand fill @ 5,297'. Well Detail Revised: 7/16/2012 by TDF « STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well U Plug Perforations U Stimulate u Other (..J Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate Isi Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development © Exploratory ❑ 207-120 •• 3. Address: 3800 Centerpoint Dr., Suite 100 Anchorage, Stratigraphic ❑ Service ❑ 6. API Number: - AK 99503 50- 733 - 20552 -00 *0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594/ ADL0018730 [Steelhead Platform] Trading Bay Unit M -17 - �® I 9. Field /Pool(s): _ 9 McArthur River Field/ Middle Kenai Gas Pool 10. Present Well Condition Summary: FEB 2 CP ti 2O12 Total Depth measured 7,670 feet Plugs measured i 7,� Q4,.,. n feet true vertical 6,380 feet Junk measured N /Ae't k-vfl8• Commission /= nchorage Effective Depth measured 7,104 feet Packer measured 5,472 feel "" —~-° —•-- 4,043 true vertical 5,886' feet true vertical 4,471 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 485' 28" 485' 484' Surface 895' 13 -3/8" 895' 894' 5,020 psi 2,260 psi Intermediate 1,430' 9 -5/8" 1,430' 1,403' 5,750 psi 3,090 psi Production 5,700 7" 5,700' 4,669' 7,240 psi 5,410 psi Liner 2,165' 5" 7,637' 6,350' 8,290 psi 7,250 psi Perforation depth Measured depth 7,073 -7,079 feet S MAR 0 x 'eW2 True Vertical depth 5,860 -5,865 feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2 #/ L -80 5,098' 4,146 Baker S -3/ ZXP 4,980'(MD), 4,043'(TVD) Packers and SSSV (type, measured and true vertical depth) Flex III Hanger 5,472'(MD), 4,4711TVD Baker T -5 426'(MD), 425'(TVD) 11. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: o 0 0 54 622 Subsequent to operation: o 2,308 0 54 399 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development El P Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil ❑ -- Gas 0 WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 16. 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: 311 -280 Contact: Melissa Eisele Phone: 777 -8319 Printed Name: Keith Elliott Title: Asset Team Leader Signature rAMMI � Phone: 777 -8300 Date 2/24/2012 Form 10-404 Revised 10/201RBr MS FEB 2 81012 2 /z,/ L � ��' p' 'Submit Original Only • •teelhead Platform Well M -17 Recompleted 02/2012 CASING AND TUBING DETAIL RKB to TBG Head 71.82' SIZE WT GRADE CONN MIN ID TOP BTM (ppt) (in.) (MDrkb) . Ili 28" Structural 27 Surface 485' 13 -3/8" 68 L -80 BTC 12.415 Surface 895' 28" Conductor 9 -5/8" 40 L -80 BTC 8.835 Surface 1430' ECP stage Collar 7" 26 L -80 BTC -M 6.276 Surface 5700' 1 ft 13 -3/8" in 17'/:" Hole 5" liner 18 L -80 H513 4.180* 5472' 7637' ECP Stage Collar Tubing 3 -1/2" 9.2 L -80 TC -II (tube) 2.992 Surface 5098' 2; (connection) 2.980 (drift) 2.867 Est TOC @ 920' *The 5 ", 18 #, FJ liner has an ID of 4.276" & a drift of 4.155 ". The H513 connection has a 4.194" machined pin ID. The Baker ZXP Flex III hanger packer assembly has a TKC x H513 X over with a 4.180" machined ID. This represents the minimum ID in the 5" liner. 1 9 -5/8" in 12 ,« Hole Top Fish: Debris from 5" drillable bridge plugs. Bottom Fish: 2.5X15' Spiral Jet EJ gun, 1 11/16" x 1.5 firing head, 1 11/16" x 1.5' magnet, 1 11/16" x 1' CCL, 1 11/16" x 1' swivel, 1 11/16" x 18' weight bar, 1 3/8" x 22' rope socket. Perforation Detail MD Date Zone Density (SPF) Notes 5782 -5788 11 -29 -07 6 5 Squeezed, Ref SCMT Log 11/22/07 5832 -5856 02 -19 -08 Squeezed, 112.5 bbls 15.8 ppg LXT 6234 -6240 11 -27 -07 6 Squeezed, Ref SCMT Log 11/22/07 7073 -7079 02 -03 -12 D -13 D3B 4 60 deg phased strip gun ' 6 w_=A' 7142 -7155 04 -05 -10 D14 6 Isolate, SLB 2 -1/2" PJ Omega HC 60 phasing - go 7296_7308 02-16-08 D -16A 6-11 Plugged/Squeezed thru cement retainer at 7213' with 3.25 bbls of 7 JI_ 7361 -7391 02 -13 -08 D -16C 6 -11 LXT cement and 2 bbls dumped on top and dressed to 7200' 8 7456 - 7470 12 - - D - 11 Isolated with 5" Posi -Set Plug at 7423' and 15.25 gals (18') of dump bailed cement. Miscellaneous Equipment Information 9 Item Depth OD ID Notes 2111111 7" Casing in 8 ' /z stole 13 3/8 x 28 ECP Stage Collar 454' Cemf d to Surf 9 5/8 x 13 3/8 ECP Stage Collar 849' Attempt to Cemt to ML 1 SCSSV 426' 5.380" 2.813" Baker TE -5 D313 Zone (sqzd plugged) 2 GLM 4 1539' 5.968" 2.867" SFO -2 3 GLM 3 3192' 5.968" 2.867" SFO -2 4 GLM 2 4245' 5.968" 2.867" SFO -2 5 GLM 1 4914' 5.968" 2.867" SFO -2 6 Production Packer 4980' 5.97" 3.900" Baker S -3 Top of 7 X Profile Nipple 5040' 4.50" 2.813" Primary 8 WLEG (bottom) 5098' 3.93" 2.960" Cement is 7034' D13 Zone 9 ZXP Flex III Hanger Packer 5472' 5.250" 4.180" Top of Cement Plug at 7104' 10 Neo plug with dump bailed cmt. 7130' »» »» Top of Cement at 7104' 10 11 5" Cement Retainer 7213' »» »» Top of Cement at 7200' D14 Top Zone Cementing Information 11 To of Cement Plu Description Volume Dens Yield Notes p l 1).,,,∎ /,,,,e (>qzd plugged) (bbls) (ppg) (ft3 /sx) I D16C Zone (sqzd plugged) 13 3/8 Stage 1 147 15.8 1.16 G GasBlok 62 bbls e .' D 17 Zone (plugged) 13 3/8 Stage 2 76 L, 188 T 15.8 1.17 G CaCI Cement to Surf, G GasBok and 4 \ 9 5/8 Stage 1 57 15.8 1.16 G GasBlok 5" Posi -Set plug at 7423' w/ 15.23 gals cmt paced w/ dump bailer (TOC 9 5/8 Stage 2 32 15.8 1.17 G GasBlok, Cmt to surf 5" Liner Shoe at 7637' tagged at 7405' ELM, 2- 11-08) 7" Production 143 12.0 2.49 G LiteCrete 6 -1 /8" Hole TD at 7670' G LXT, Partial to complete losses, 5" Liner Primary 49.5 15.8 1.2 packed off. TOC @ 7034' per SCMT MAX HOLE ANGLE' 5" Circ. Sqz. 6240' -5782' 16.5 15.8 1.2 G LXT, Partial to complete losses. 5" Balanced Plug across D3B and 21 15.8 1 21 G LXT, Partial returns, plug was 56.4° @ Tangent 2,796' MD old Sqz Perfs ineffective G LXT, down sqz thru cmt. ret., 1" plug (1 plug) 45 bbls a 5" Sqz Plug across D3B a broke down at 1150 psi, 2" plug held (2 plug jobs) (2 plug) 46.5 15.8 1.21 hydrostatic column, no surface pressure bbls test 5" Downsqz thru cmt. retainer for 3.25 15.3 1.21 G LXT, down sqz thru cmt. ret. D16A and D16C 5" Cmt. Plug on top of retainer G LXT, dumped 2 bbls on top of above D16A and DI6C 2 15.3 1.21 retainer and polished to 7200' Well Detail Revised: MEE 02/21/12 • r • • 111 Hilcorp Alaska LLC Project Operations Summary Well Name API Number Well Permit Number Start Date End Date Steelhead M -17 50-733-20552-00 207 120 1/27/12 2/3/12 �� � �,; ,, � .i - - K #� 111. it 41,: � 4 h� rF ' 1/27/2012 to /'/.2012 - Friday RU wireline. Pressure test lubricator to 250psi low and 3,000psi high. RIH w/ 2.77" GR and tag fill at 7,188' RKB. POOH. RIH w/ 2.5 "x40' bailer (as dummy gun) to 7,188'. POOH. 1/28/2012, RU E -line. Pressure test lubricator to 250psi low and 3,000psi high. RIH with plug and set at 7,130'. POOH. RIH w/ 2 -1/2 "x20' dump bailer and place 5.6' of cement on top of plug at 7,130'. POOH. 1/29/2012 to 1/30/2012 - Sunday RU E -line. Pressure test lubricator to 250psi low and 3,000psi high. RIH w/ 2.70" LIB and close vent on plug at 7,120'. POOH. RU 2 -1/2 "x40' cement dumb bailer and RIH twice, placing cement to 7,100'. POOH and RD. 1/30/2012 to 1/31/2012 Monday Pressure tubing up to 920psi for positive pressure test on plug. Jim Regg (AOGCC) waived witness to tag tomorrow. 1/31/2012 to 2/1/2012 - Tuesday Complete positive test. Pressure test lubricator to 250psi low and 3,000psi high. RIH w/ 2.70" GR and press/ temp tool, tag top of cement at 7,111. POOH. 2/121`1x/ „2012 - Wednesday RIH with 2 -1/2 "x20' bailer of water. Placed water at 7111'. Dump bail 5.7' of cement from 7111' to 7104'. 2/2/2012 to 2/3/2012 - Thursday Bled tubing pressure down to 300 psi for negative test and well started pressuring up, test failed. Received waiver from Guy Schwartz (AOGCC) to continue with procedure and perforate. Perforated from 7075' to 7077' with 2 perf pods to equalize /, ///14/1"---2 l � • Hilcorp Alaska LLC Project Operations Summary Well Name API Number Well Permit Number Start Date End Date Steelhead M -17 50- 733 - 20552 -00 207 -120 1/27/12 2/3/12 .1 .PP , 2/3/2012 to 2/4/2012 - Friday RIH with 2- 1/2 "x6', 4spf, 60 degree strip gun and perforated from 7073' to 7079'. POOH and rig down. Turn well over to production. ,,100 • • o[F nInsEn, SEAN PARNELL, GOVERNOR GAS OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg 1 2-67 Drilling Manager Union Oil Company of California P.O. Box 196247 .tv° k.?. ) S EP .+ 201; Anchorage, AK 99519 Re: McArthur River Field, Middle Kenai Gas Pool, Trading Bay Unit M -17 Sundry Number: 311 -280 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. 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, Daniel T. Seamount, Jr. Chair DATED this 3 day of September, 2011. Encl. • STATE OF ALASKA �,`� I ''+' REC ° `ED ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 12 2011 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Oi18r cgs Gaga. C ommissit� 1. Type of Request: Abandon ❑ Plug for Redrill El Perforate New Pool El Repair Well & A ft pprov Program Suspend ❑ Plug Perforations 0 • Perforate El • Pull Tubing ❑ AflChOf I n Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development EI + Exploratory ❑ 207 -120 + 3. Address: Stratigraphic El Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 733 - 20552 -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 0 ' Trading Bay Unit M -17 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0017594/ADL0018730 [Steelhead Platform] • McArthur River Field/ Middle Kenai Gas Pool • 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): 7,670. 6,380 • 7,200 5,968 7,200' N/A Casing Length Size MD TVD Burst Collapse Structural / Conductor 485' 28" 485' 484' Surface 895' 13 -3/8" 895' 894' 5,020 psi 2,260 psi Intermediate 1,430' 9 -5/8" 1,430' 1,403' 5,750 psi 3,090 psi Production 5,700' 7" 5,700' 4,669' 7,240 psi 5,410 psi Liner 2,165' 5" 7,637' 6,350' 8,290 psi 7,250 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,142 -7,155 5,919 -5,930 3 -1/2" 9.2 #/ L -80 5,098 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker S -3; ZXP Flex III Hanger Packer and Baker T -5 4,980(MD), 4,043(TVD); 5,472(MD), 4,471(TVD) and 426(MD), 425(TVD) 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: /1/11/ 11 Oil ❑ Gas 0 ' f WDSPL ❑ Suspended ❑ 16. Verbal Approval: \ Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Billy Applewhite Phone: 263 -7671 Printed Name Timothy C. Brandenburg Title Drilling Manager IOW t/ Signature -� Phone 276 -7600 Date 9/7/2011 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 1-3..) Plug Integrity R/ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: i D_ ii O 4 APPROVED BY 9) / 3/ Approved by: / COMMISSIONER THE COMMISSION RIZ � 1�lNAL Date: 1 S ubmit in Duplicate . Form 10-403 Revised 1/2010 ( SEP 1 20 a ' R .i( � Chevron • •eelhead Platform . 1%0 Actual Well M -17 %. Recompleted 4/5/2010 CASING AND TUBING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM RKB to TBG Head 71.82' (ppt) (in.) (MDrkb) 28" Structural 27 Surface 485' li 13 -3/8" 68 L -80 BTC 12.415 Surface 895' 28" Conductor 9 -5/8" 40 L -80 BTC 8.835 Surface 1430' ECP Stage Collar 7" 26 L -80 BTC -M 6.276 Surface 5700' 13 -3/8" in 17 i" Hole 5" liner 18 L -80 H513 4.180* 5472' 7637' is 1 Tubing ECP Stage Collar 3 -1/2" 9.2 L -80 TC -II (tube) 2.992 Surface 5098' (connection) 2.980 2 (drift) 2.867 Est TOC @ 920' *The 5 ", 18 #, FJ liner has an ID of 4.276" & a drift of 4.155 ". The H513 connection has a 4.194" machined pin ID. The Baker ZXP Flex III hanger packer assembly has a TKC x H513 X over with a4.180" machined ID. This 3 represents the minimum ID in the 5" liner. t. 1 9 -5/8" in 12 "Hole Top Fish: Debris from 5" drillable bridge plugs. Bottom Fish: 2.5X15' Spiral Jet EJ gun, 1 11/16" x 1.5 firing head, 1 11/16" x 1.5' magnet, 1 11/16" x 1' CCL, 1 11/16" x 1' swivel, 1 11/16" x 18' weight bar, 1 3/8" x 22' rope socket. 4 ' Perforation Detail MD Da Z one Density (SPF) Notes 5782 - 5788 11 - 29 - 07 6 Squeezed, Ref SCMT Log 11/22/07 > X' - c,` , h , ) , _Ic)_tiS )It `tluCezeci ! i_`. 111 li.�+pl �! `' 5 6234 -6240 11 -27 -07 6 Squeezed, Ref SCMT Log 11/22/07 t of I am 1 7142 -7155 04 -05 -10 D14 6 SLB 2 -1/2" PJ Omega HC 60 phasing 6 „ - >( > - ■t Ih.18 i5 - 1' \, - i l Plugged (Squeezcd thru cement retainerat 7213' with 3.25 bbls of LXT cement and 2 8 bbls dumped on top and dressed to 7200' I _ti 0 ! ' i Isolated with S' Pose -Set Plug at 7423' and 1525 gals (18') of dump bailed cement. i 9 All Miscellaneous Equipment Information Item Depth OD ID Notes 7" Casing in 8'/" Hole 13 3/8 x 28" ECP Stage Collar 454' Cemt'd to Surf 9 5/8 x 13 3/8 ECP Stage Collar 849' SCSSV Attempt to Cemt to ML 1 426' 5.380" 2.813" Baker TE -5 D3B zone (sgzd plugged) 2 GLM 4 1539' 5.968" 2.867" SFO -2 3 GLM 3 3192' 5.968" 2.867" SFO -2 4 GLM 2 4245' 5.968" 2.867" SFO -2 5 GLM 1 4914' 5.968" 2.867" SFO -2 6 Production Packer 4980'- 5.97" 3.900" Baker S -3 7 X Profile Nipple 5040' 4.50" 2.813" 8 WLEG (bottom) 5098' 3.93" 2.960" 9 ZXP Flex III Hanger Packer 5472' 5.250" 4.180" Pop of Primary 10 5" Cement Retainer 7213' » Top » »» To of Cement at 7200' Cement is 7034' ' D14 Zone Cementing Information - Description Volume Dens Yield Notes Top of Cement Plug at 7200' >u (bbls) (ppg) (ft3 /sx) D16A Zone (sgza plugged) 13 3/8 Stage 1 147 15.8 1.16 G GasBlok • r rs D16C Zone (sqzd plugged) 13 3/8 Stage 2 76 L, 188 T 15.8 1.17 62 bbls Cement to Surf, G GasBok and G CaCI e DI7 tone (pk oed) 95/8 Stage 1 57 15.8 1.16 GGasBlok A 9 5/8 Stage 2 32 15.8 1.17 G GasBlok, Cmt to surf lh 5" Posi -Set plug at 7423' w/ 1523 gals cmt placed w/ dump bailer (TOC 7" Production 143 12.0 2.49 G LiteCrete 5" Liner Shoe at 7637' tagged at 7405' ELM, 2 -11 -08) 5" Liner Primary 49.5 15.8 1.2 G LXT, Partial to complete losses, 6 -1/8" Hole TD at 7670' packed off. TOC @ 7034' per SCMT 5" Circ. Sqz. 6240' -5782' 16.5 15.8 1.2 G LXT, Partial to complete losses. MAX HOLE ANGLE • 5" Balanced Plug across D3B and 21 15 8 1 21 G LXT, Partial returns, plug was old Sqz Perfs ineffective 56.4° @ Tangent 2,796' MD (1' plug) 45 bbls G LXT, down sqz thin cmt ret, l" plug g 5" Sqz Plug across D3B a broke down at 1150 psi, 2" plug held (2 plug jobs) (2" plug) 46.5 15.8 1.21 hydrostatic column, no surface pressure bbls test 5" Downsgz thru cmt, retainer for 3.25 15.3 1.21 G LXT, down sqz thru cmt. ret. DI 6A and D 16C 5" Cmt. Plug on top of retainer 2 15 3 1 21 G LXT, dumped 2 bbls on top of above D16A and D16C retainer and polished to 7200' • Well Detail DRAWN BY: JAR 2/19/2008 Updated: 05/03/2010 RMS • Chevron • leelhead Platform , % . PROPOSED . Well M -17 %. Recompleted 4/5/2010 CASING AND TUBING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM RKB to TBG Head 71.82' (ppt) (in.) (MDrkb) 28" Structural 27 Surface 485' 13 -3/8" 68 L -80 BTC 12.415 Surface 895' ( I 28" Conductor 9 -5/8" 40 L -80 BTC 8.835 Surface 1430' 41. ECP Stage Collar 7" 26 L -80 BTC -M 6.276 Surface 5700' 1 13 -3 /8" in 17 1/4" Hole 5" liner 18 L -80 H513 4.180* 5472' 7637' ECP Stage Collar Tubing 3 -1/2" 9.2 L -80 TC -II (tube) 2.992 Surface 5098' 2 (connection) 2.980 (drift) 2.867 Est TOC @ 920' *The 5 ", 184, FJ liner has an ID of 4.276" & a drift of 4.155 ". The 11513 connection has a 4.194" machined pin ID. 3 I The Baker ZXP Flex III hanger packer assemblyhas a TKC x H513 X over with a4.180" machined ID. This ` , 9 -s/8" in 12/.^ Hole represents the minimum ID in the 5" liner. . \Top Fish: Debris from 5" drillable bridge plugs. o r Botto Fish: 2.5X15' Spiral Jet EJ gun, 1 11/16" x 1.5 firing head, 1 11/16" x 1.5' magnet, 4 ` v T ii,N 0 1 11/16" x 1' CCL, 1 11/16" x 1' swivel, 1 11/16" x 18' weight bar, 1 3/8" x 22' rope socket. P Perforation Detail f MD Date Zone Density (SPF) Notes A (� +/- 5146' -5166' Contingency c5 5 V V 5782 - 5788 11 -29 -07 6 Squeezed, Ref SCMT Log 11/22/07 1 ma , A , N 5832 - 5856 02 -19 -08 D3B 5 Squeezed, 112.5 bbls 15.8 ppg LXT 6 = to Q e +/ 6169' - 6179' contingency D - 6 7 (' 6234 -6240 11 -27 -07 6 Squeezed, Ref SCMT Log 11/22/07 8 �/ +1- 7071' -7081' Proposed D -13 6 7142 -7155 04 -05 -10 D14 6 Isolate, SLB 2 -1/2" PJ Omega HC 60 phasing 7296 -7308 02 -16 -08 D -16A 6-11 Plugged/Squeezed thru cement retainer at 7213' with 3.25 bbls of 7361 -7391 02 -13 -08 D -16C 6 -11 LXT cement and 2 bbls dumped on top and dressed to 7200' 7456 -7470 12 -21 -08 D -17 11 Isolated with 5" Posi -Set Plug at 7423' and 15.25 gals (18') of dump bailed cement. 9 )1111 Miscellaneous Equipment Information 7" Casing in 8 %° Hole , Item Depth OD ID Notes C5 Zone (Contingency) / 13 3/8 x 28" ECP Stage Collar 454' Cemt'd to Surf rl;lt 7 , 9 5/8 x 13 3/8 ECP Stage Collar 849' Attempt to Cemt to ML 1 SCSSV 426' 5.380" 2.813" Baker TE -5 2 GLM 4 1539' 5.968" 2.867" SFO -2 / D -6 zone (Contingency) 3 GLM 3 3192' 5.968" 2.867" SFO -2 4 GLM 2 4245' 5.968" 2.867" SFO -2 5 GLM 1 4914' 5.968" 2.867" SFO -2 6 Production Packer 4980' 5.97" 3.900" Baker S -3 - D13 Zone (Proposed) 1 7 X Profile Nipple 5040' 4.50" 2.813" Top of 8 WLEG (bottom) 5098' 3.93" 2.960" Primary TOC 7100' (Proposed) Cement tatter Hanger 9 ZXP Flex III H er Packer 5472' 5.250" 4.180" Ce is 7034' Plug w /30' cement on top +/ -7100' Proposed Dl4 Zone 10 5" Cement Retainer 7213' »» »» Top of Cement at 7200' 10 �____ Top of Cement Plug at 7200' D16A Zone(sgzd pigged) Cementing Information D16C Zone (wzd ulueaed) Description Volume Dens Yield Notes (bbls) (ppg) (ft3 /sx) D17 Lone (plugged) 13 3/8 Stage 1 147 15.8 1.16 G GasBlok 5" Post - set plug at 7423' w/ 15.23 13 3/8 Stage 2 76 L, 188 T 15.8 1.17 62 bbls Cement to Surd G GasBok and gals cmt placed w/ dump bailer (TOC G CaCI 5" Liner Shoe at 7637' tagged at 7405' ELM, 2 - 11 9 5/8 Stage 1 57 ' 15.8 1.16 G GasBlok 6 -1 /8" Hole TD at 7670' 9 5/8 Stage 2 32 15.8 1.17 G GasBlok, Cmt to surf 7" Production 143 12.0 2.49 G LiteCrete MAX HOLE ANGLE: 5" Liner Primary 49.5 15.8 1.2 G LXT, Partial to complete losses, • packed off. TOC na, 7034' per SCMT 56.4° @ Tangent 2,796' MD 5" Circ. Sqz. 6240' -5782' 16.5 15.8 1.2 G LXT, Partial to complete losses. 5" Balanced Plug across D3B and 21 15.8 1 21 G LXT, Partial returns, plug was old Sqz Perfs ineffective G LXT, down sqz thru cmt. ret., 1 plug 5" Sqz Plug across D3B (1" plug) 45 bbls broke down at 1150 psi, 2n plug held (2 plug jobs) (2 " plug) 46.5 bbls 15.8 121 hydrostatic column, no surface pressure test 5" Downsqz thru cmt. retainer for 3.25 15.3 1.21 G LXT, down sqz thru cmt. ret. D16A and D16C 5" Cmt. Plug on top of retainer G LXT, dumped 2 bbls on top of above D16A and D16C 2 15.3 1.21 retainer and polished to 7200' Well Detail Revised: TDF 8/24/11 Chevron • • Trading Bay Unit Well #M -17 9/7/2011 OBJECTIVES: • Isolate D - 14 zone and perforate the D - 13 zone with contingency to isolate and /or perforate the D and C - 5 zones. Current BHP: 1163 psi @ 5920' TVD Max DowSsole Pressure: 2567 psi @ 5860' TVD (Bas on virgin pressure gradient of 0.45psi /ft of TVD) MASP: 210 (Based on a pressure gradient of 06 psi/ foot of TVD) PROCEDURE SUMMARY: 1. RU (Slickfine. Pressure test lubricator 250psi low /3000psi high. 2. RIH with gauge ring and tag fill at ( + / -) 7200'. 3. RIH with dummy gun to ( + / -) 7150'. 4. Rig down slickline. 5. R Elide. Pressure test lubricator 250psi low /3000psi high. 6. Set Plug at +/- 7,130'. 7. Dump bail +/- 30' of +/ -16 ppg cement on top of plug in 5" casing from +/- 7,130' to +/- 7,100'. WOC. 8. Perform positive test to +/- 1000 psi for 12 hrs. Chart test. 9. Perform negative test to +/ -200 psi for 12 hrs. Chart test. RIH tag TOC. 10. Perforate the D -13 sand from +/- 7,071' to +/- 7,081'. 11. Rig down E -line. 12. Turn well over to production. Flow test well. Contingency #1 — Add the D -6 sand pending results of production testing of the D -13 sand. l 1. Rig u E -line. Pressure test lubricator 250psi low /3000psi high. 2. Perforate D -6 zone from +/- 6,169' to +/- 6,179'. 3. Rig down E -line. 4. Turn well over to production. Flow test well. Contingency #la — Isolate the D -13 sand and add the D -6 sand pending results of production testing of the D -13 sand. 1. Rig up E -line. Pressure test lubricator 250psi low /3000psi high. 2. Set plug at +/- 7,050'. 3. Dump bail +/- 30' of +/ -16 ppg cement from +/- 7,050' to +/- 7,020'. WOC. chevron • Trading Bay Unit I 110 Well # M -17 1%10 9/7/2011 4. Perform positive test to + /- 1,000psi and chart for 12 hours. 5. Perform negative test to +/ -200 psi and chart for 12 hours. RIH tag TOC. 6. Perforate D -6 zone from +/- 6,169' to +/- 6,179'. 7. Rig down E -line. 8. Turn well over to production. Flow test well. Contingency #2 — Add the C -5 sand pending results of production testing of the D -6 sand. 5. Rig up E -line. Pressure test lubricator 250psi low /3000psi high. 6. Perforate C -5 zone from +/- 5,146' to +/- 5,166'. 7. Rig down E -line. 8. Turn well over to production. Flow test well. Contingency #2a — Isolate the D -6 sand and perforate the C -5 sand pending results of production testing of the D -6 sand. 9. Rig up E -line. Pressure test lubricator 250psi low /3000psi high. / 10. Set plug at +/- 6,150'. 11. Dump bail +/- 30' of +/ -16 ppg cement from +/- 6,150' to +/- 6,120'. WOC. 12. Perform positive test to + /- 1,000psi and chart for 12 hours. 13. Perform negative test to +/ -200 psi and chart for 12 hours. RIH tag TOC. 14. Perforate C -5 zone from +/- 5,146' to +/- 5,166'. 15. Rig down E -line. DATA SUBMITTAL COMPLIANCE REPORT 3/1/2011 Permit to Drill 2071200 Well Name /No. TRADING BAY UNIT M -17 Operator UNION OIL CO OF CALIFORNIA API No. 50- 733 - 20552 -00 -00 MD 7670 TVD 6380 Completion Date 12/29/2007 Completion Status 1 -GAS Current Status 1 -GAS UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey 4 1-...------ DATA INFORMATION Types Electric or Other Logs Run: GR / RES / DEN / MAG RES / CMT (data taken from Logs Portion of Master Well Data Maint III Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments Log Induction /Resistivity 5 Col 490 7670 Open 1/4/2007 MPR, CNP, Comp Bulk Den, GR Mem Log 17 -Nov- 1 2007 D C Las 15814/ Pressure 0 0 Open 1/4/2007 Pres, RPM Rpt 15818 Report: Final Well R 0 0 Open 1/4/2008 Final Well Report, Table of Cont, Equip & Crew, Well Details, Geo Data, Drill Data, Daily Reports, Form and Drill Logs w/ Graphics in PDF V 15818 Mud Log 2 Col 485 7670 Open 1/4/2008 MD Formation Log tog 15818 Mud Log 2 Col 485 7670 Open 1/4/2008 TVD Formation Log k,Log 15818 Mud Log 2 Col 485 7670 Open 1/4/2008 TVD Drilling Dynamics • VLog 15818 Mud Log 2 Col 485 7670 Open 1/4/2008 MD Drilling Dynamics .-Cog 15818 See Notes 2 Col 485 7670 Open 1/4/2008 MD LWD Combo Log KO 15818 Ma�ud Log 2 Col 485 7670 Open 1/4/2008 TVD LWD Combo Log D C Las 16009 ' duction /Resistivity 1400 5712 Open 3/10/2008 GR, DEN, RPC, RPM, t og Formation Micro Ima 2 Col 1450 5650 Open 3/10/2008 Formation Eval, Mag Resonance i ' Fp C Las 16084 `'Mud Log 401 7700 Open 4/5/2008 Mud Logs, in LAS format • og Perforation 5 Col 5832 5856 Case 6/10/2008 Perf Rec 2.5" PWRSP, 5SPF CCL DATA SUBMITTAL COMPLIANCE REPORT 3/1/2011 Permit to Drill 2071200 Well Name /No. TRADING BAY UNIT M -17 Operator UNION OIL CO OF CALIFORNIA API No. 50- 733 - 20552 -00 -00 MD 7670 TVD 6380 Completion Date 12/29/2007 Completion Status 1 -GAS Current Status 1 -GAS UIC N t/>`D C Pds 16420s 5832 5856 Case 6/10/2008 Perf Rec 2.5" PWRSP, 5SPF CCL /Log See Notes 5 Col 5782 7374 Case 6/10/2008 Depth Determ, 2.5" bottom nose CCL D C Pds 16421' Notes 5782 7374 Case 6/10/2008 Depth Determ, 2.5" bottom • og nose CCL -53Pr CCL 16422 Perforation 5 Col 7298 7381 Case 6/10/2008 Perf Rec 2.5" PWRSP, 5SPF CCL 16 Feb, 2008 / s4D C 15818 Report: Final Well R 0 0 Open 1/4/2008 Final Well Report, Table of Cont, Equip & Crew, Well Details, Geo Data, Drill Data, Daily Reports, Form and Drill Logs w/ Graphics in PDF ✓ED C 19811VInduction /Resistivity 450 7670 Open 6/29/2010 Final, Mud Logs, Survey in // LAS, PDS and LIS graphics D Pds 16422 +Perforation 7298 7381 , Case 6/10/2008 Perf Rec 2.5" PWRSP, 5SPF CCL 16 Feb, 2008 og 16421 See Notes 5 Col 5782 7374 Case 6/10/2008 Depth Determ, 2.5" bottom nose CCL og See Notes 5 Col 6889 7430 Case POSISET Plug Setting • Record MPBT CCL t' og Pressure 5 Col 5636 7398 Case Pressure Temperature Log PBMS GR/CCL Log Perforation 5 Col 7296 7391 Case 6/10/2008 Perf Rec 2.5" PWRSP, 5SPF CCL Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 3/1/2011 Permit to Drill 2071200 Well Name /No. TRADING BAY UNIT M -17 Operator UNION OIL CO OF CALIFORNIA API No. 50- 733 - 20552 -00 -00 MD 7670 TVD 6380 Completion Date 12/29/2007 Completion Status 1 -GAS Current Status 1 -GAS UIC N ADDITIONAL INFORMATION / Well Cored? Y� Daily History Received? 1 Y) N Chips Received? - "1'`7°tr Formation Tops 0)N Analysis Y'f� R • eceived? Comments: Compliance Reviewed By: —_._ Date: • • I Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tele: 907 263 7844 Fax: 907 263 7828 E -mail: fcbn @chevron.com DATE June 28, 2010 iA l r,, To: AOGCC Mahnken, Christine R _ ,, ` ]:11 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 r jsa Da -:z .... 7a 1: ,. s . DATA TRANSMITTAL Transmitted herewith is one DVD containing the following data. • D -48L1 � ��� • Formation evaluation logs - LAS t9Vj 0? • Gamma ray logs - LAS -- • K -12RD2 0,0). if-41 / cP 13176 • K- 12RD2_Final_Survey.xls • K- 12RD2_Tops.xlsx o0t _. l Clj 66, • MPR -Gamma ray logs - LAS, CGM, PDF • K -18RD �0 1- /J /916- • K- 18RD_Final_Survey.doc • Density Neutron logs - LAS / /� , / 9 f5L t • K- 18RDPB1 • UBI log - LAS, PDS, DLIS 00_ 4 1 / 4 j7)b 7 • survey . xls / / 9 Z/6 • K -24RD2 cP to • Density Neutron logs - LAS • _ Final _ Report - LAS, DOC 002 - AO C) t $�, M -06 - - ----- �._/ F • Final logs; Depth, Formation Evaluation, Realtime, Time - LAS, PDS, DLIS M -10 d�S _ /(O � 1'3 • M -10PB1 USIT log • USIT log -PDS 0 /9 )33 • Final logs; Depth, Formation Evaluation, Realtime, Time - LAS, PDS, DLIS • Final logs; Depth, Formation Evaluation, Realtime, Time - LAS, PDS, DLIS • M -16RD / ',9- /' (`f /c( • M- 16RD_Tops.xlsx • Final logs; Cement Bond Log, Completion Record -PDS • M -17 • M- 17_Tops.xlsx • M17_MWD_Survey.pdf • Final Mudlog Report - LAS, DOC, DBF, MDX, PDF, DAT • Final logs; Depth, Formation Evaluation, Cement Bond, Plug Setting, Perforation - LAS, PDS, DLIS, TIFF Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Cya --- Date: iag ' RECEIVED STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSIO MAY 0 5 2010 REPORT OF SUNDRY WELL OPERATIONS 1. Opera :. ,:4,.. k UGaG Repair Well LJ Plug Perforations Li Stimulate (J Other IA Fill Cleanout Performe . fjg ❑ Pull Tubing 0 Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate El Re -en er Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: '6. Permit to Drill Number: Name: Development 12 Exploratory 207 -120 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic El Service ❑ API Number: 50- 733 - 20552 -00 7. Prop ty Desigrta on (Lease Number): . Well Name and Number: ADL017594, ADLO18730 [Steelhead Platform] Trading Bay Unit M -17 9. Field /Pool(s): McArthur River Field / Middle Kenai Gas Pool 10. Present Well Condition Summary: Total Depth measured 7,670 feet Plugs (measured) 7,200 (cement) feet true vertical 6,380 feet Junk (measured) N/A feet Effective Depth measured 7,200 feet Packer (measured) 4,980 feet true vertical 5,968 feet (true vertical) 4,043 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 485' 28" 484' 484' Surface 895' 13 -3/8" 895' 894' 5,020 psi 2,260 psi Intermediate 1,430' 9 -5/8" 1,430' 1,403' 5,750 psi 3,060 psi Production 5,700' 7" 5,700' 4,669' 7,240 psi 5,410 psi Liner 2,165' 5" 7,637' 6,350' 10,140 psi 10,500 psi Perforation depth: Measured depth: 7,142'- 7,155' True Vertical depth: 5,919'- 5,930' Tubing (size, grade, measured and true vertical depth): 3 -1/2" 9.2# L -80 5,098' MD 4,146' TVD Packers and SSSV (type, measured and true vertical depth): Baker S -3 Packer 4,980'MD / 4,043'TVD Baker TE -5 SCSSV 426'MD / 425'TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): D -16A (7,296'- 7,308'), D -16C (7,361'- 7,391'), and D -3B (5,832' - 5,856') Treatment descriptions including volumes used and final pressure: D -3B - 21bbI 15.8ppg LXT cement balanced plug, D -3B - 45 bbl 15.8ppg LXT cement through retainer, final squeeze pressre 2100 psi D -3B - 46.5 bbl 15.8ppg LXT cement through retainer, final squeeze pressre 1550 psi D -16A & D -16C - 3.2bbI ppg LXT cement through retainer, final squeeze pressure 1750 psi, with 2bbl cement on top of retainer 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 200psi Opsi Subsequent to operation: 0 4,110 0 200psi 1,175psi 13. Attachments: �. Well Class after work: Copies of Logs and Surveys Run N/A ` Exploratory❑ Development El Service ❑ Daily Report of Well Operations X WeiI Status after work: Oil ❑ Gas El WDSPL U GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 16. 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: 310 -044 Contact Ronnie Santos 263 -7978 Printed Na ri, Timothy C. Brandenburg Title Drilling Manager Signature ✓ Ph 276 -7600 Date 5/4/10 Form 10.404 R..—d 7/2009 Ht3DMS MAY 0 6 101 s11 sut ,,,,x O.; ,al O. Iy Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -17 TRADING BAY UNIT M -17 ADL017594; ADL018730 5073320552 LB2629 160.00 185.00 ,,, to . Primary Completion . o Recomplete from D3B sands to the D14 Sand. 3/3/2010 3/31/2010 Work Over (MRWO) Primary Wellbore Affected Wellbore UVVI Well Permit Number 507332055200 1 11 'Dal 0. tfo ; "* k', :. 3/4/2010 :00 - 315/2010 00:00 Operations Summary Skid drill package over M -17. Conduct Pre Spud Meeting. RU other equipment. RU slickline unit, pressure test lubricator 250psi low /2000psi high. Failed to pull lowermost GLM orifice in first attempt. Called AOGCC Jim Regg at 16:10 hours about upcoming BOP test. 3%5/2010 00 :00 - 3/6/2010 00:00 Y , z •.. r . -w Operations Summary POH with orifice from lowermost GLM. RD slickline RU to fill well with FIW. Pressure test lines to 3000 psi. Pump hole capacity with FIW. Monitor well, no loss or gain. Set BPV. ND production tree. NU riser & BOP. Install 3 1/2" rams in upper gate and leave bottom rams empty. Connect choke and kill lines. Connect koomey lines, install bell nipple, and changeout saver sub. Received call from Jim Regg of AOGCC at 15:12 hours, waived wittness for BOP test. 3/6/2010 00:00 - 317/2010 00 :0f ., ��' `` Operations Summary Pressure test BOPE per AOGCC requirement: Annular 200 psi low and 1000 psi high; Rams 200 psi low and 3000 psi high with 3 -1/2" drill pipe. Attempt to pull 3 -1/2" tubing. Circulate and work string from 65k to 215k. Move string up 7 feet. Unable to pull 3 -1/2" production tubing out of seal assembly. 3/712010.00;00 - 3/512010 00:00 Operations Summary Work tubing without success. RU and run 2.70" jet cutter. Cut 3 1/2" tubing at 5,441' MD. POOH and RD WL. Establish circulation and tubing free. Circulate at 12 BPM with 1800 psi. Recovered 0.75 bbls sand out of hole. POOH laying down 3 -1/2" tubing. 3 t> 6 00 :0 °3/912010 0000 Operations Summary Waiting on weather. Perform rig maintenance. Continue POOH and lay down 3 -1/2" tubing. 3181201000:00`-3/10/2010 Operations Summary RU hawk jaw. Set wear bushing. RIH wash over fish from 5,441' to 5,470' MD. Circulate B /U. POOH and lay down wash pipe. MU over shot and RIH. Work to engage fish. Circulate B /U. 340,2010/0(g00-, 3/11/2010400:00 Operations Summary POOH. Recovered 100% of tubing fish. RIH with polish mill assembly and 1 jt stinger. Polish seal bore. Circulate hole clean. No sand recovered. No losses. P001-1. RIH with seal assembly and sting into the seal bore. Pressure test liner top and 7" casing to 3000 psi for 30 minutes. POH LD fishing equipment. PU cleanout BHA. 3/11/2010 00 :00 - 3/12/2010 000 4 ry as Operations Summary PUMU 4 -1/8" Bit and BHA. PU and RIH 51 joints 2 -7/8" DP. PUMU tandem BHA consisting of 7" scraper, 7" magnet, and circulating sub. RIH with 3 -1/2" DP to 5,384'. Break circulation and establish parameters in 7" casing. Continue RIH no problems through 5" liner top to 5,735'. Cleanout fill to 5,850' and lost returns. Pump 60 bbl sized salt LCM pill. Loss rate at 96 bph after first LCM pill. Monitor well on trip tank while mixing second LCM pill. 3 00:00 - 3113%2010 00:00 ,,. .. Operations Summary Pump 61 bbls sized salt pill and monitor well on trip tank. Losses at 15 bph. Continue RIH to 5,766'. MU TDS and RIH without pumps to tag sand at 5,865'. Cleanout sand to 6,144'. Losses at 60 bph. Continue cleanout in the 5" liner pumping 5 bbl sweep with calcium carbonate after each stand to 7,098'. 3/13/2010 00:00 - 3/14/2010 00:00 a., Operations Summary Cleanout 5" liner to 7,356' solid bottom and unable to progress. Circulate hole clean. POOH above top perfs to 5,638'. Circulate hole clean. Squeezed 20 bbl sized salt pill into the open perfs. POOH LD casing cleanout BHA. POOH 2 -7/8" DP and BHA to surface. Monitor well. Losses at 16 bph. PUMU 5" composite bridge plug and setting tools. RIH to 5,382'. Notified AOGCC at 10:15H, 3/12/10 of upcoming BOPE test. Chuck Scheve returned call at 15:20H and agreed to postpone until scheduled cement squeeze is in place. 4x2010 00:00 - 3/15/2010 00:00 Operations Summary Set composite bridge plug at 6,369' and POOH setting tools. RIH with 40 joints of 2 -3/8" tubing. Continue RIH with 3 -1/2" DP to top of bridge plug. Lay a 21 bbl 15.8 ppg LXT balanced cement plug. Under displace plug by 3.5 bbls. POOH slowly with 11 stands. Well took 12.8 bbls more than calculated steel displacement. Reverse circulate tubing capacity. Recovered 5 bbls contaminated cement. Pull 3 stands and circulate BTU at 5,000'. POOH to 1,870'. Loss rate 14 - 20 bph. Chevron • • NI/ Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -17 TRADING BAY UNIT M -17 ADL017594; ADL018730 5073320552 LB2629 160.00 185.00 - rations` "r arc. " O 3/15/2010 00:00 - 3/16/2010 00:04?...; ': t Operations Summary POOH LD 2 -3/8" tubing. RIH with 4 -1/8" Mill Tooth Bit and BHA. Tag cement at 5,850'. Drillout to firm cement at 5,860'. Circulate hole clean. POOH. MU EZ -Drill Cement Retainer. RIH and set at 5,660'. Disengage tool from retainer and confirm set. Establish injection rates. AOGCC's Chuck Scheve planned to arrive at Steelhead on 07:30H chopper, 3/16/10 for BOPE test. 3/18/201000:00 .8/17120'04 4 Operations Summary Mix and pump 50 bbls of 15.8 ppg LXT cement. Squeeze 45 bbls into formation through the cement retainer. Final squeeze pressure = 2100 psi at 4 BPM. Reverse circulate excess cement. POOH LD BHA. Test annular preventer to 250/1000 psi, test 3 -1/2" rams and other BOPE equipment to 250/3000 psi. Perform accumulator drawdown test. Tests witnessed by AOGCC - Check Scheve. PUMU RIH with 4 -1/8" junk mill and BHA. Tag cement at 5,632'. Cleanout cement to 5640'. 312010 00 :00 - ` 3/18/2010 40 :00.' Operations Summary Cleanout cement to the top of cement retainer at 5,660'. Mill cement retainer and cleanout cement to 5799'. CBU. Test casing across the top squeeze perfs to 1250 psi. Pressure bled to 1150 psi in 30 minutes. Cleanout cement to 5,870'. Attempt to pressure test well across D3B. Pressured up to 1150 psi and broke down formation injecting at 900 psi with 2 BPM. Static losses at 6 BPH. POOH. 3/18 /20'10.00 :00 - 3/1912010;00:00 Operations Summary L/D BHA. RIH and set cement retainer at 5,690'. Establish injection rates. Mix and pump 50 bbls of 15.8 ppg LXT cement. Squeeze 46.5 bbls into formation through the cement retainer. Final squeeze pressure = 1550 psi at 2 BPM. Reverse circulate excess cement. POOH LD setting tool. 3/19/2010 00:00 - 3/20/2010 00:00 Operations Summary RIH with 4 -1/8" junk mill and cleanout BI-IA to top of cement at 5,602'. Cleanout cement to the top of cement retainer at 5,692'. Mill up cement retainer and cleanout cement to 5,897'. 2/20/2010 00:00 - 3/21 /2010 00 :00 �. . . Operations Summary Cleanout cement to the top of composite bridge plug at 6,367'. Drillout composite bridge plug and RIH to chase debris to 7,340'. Shut -in well and circulate out gas through open choke. Circulate hole clean. POOH LD DC's. 3/21#010000., 4: Operations Summary PU and RIH with cement retainer. Tagged at 7,240'. Work tight hole. Set cement retainer at 7,213'. Log RA tag to correlate retainer set at depth. Squeezed 3.25 bbls of 15.3 ppg LXT cement below the retainer. Final squeeze pressure = 1750 psi at 1 BPM. Dumped 2 bbls of cement on top of retainer. Pull one stand and CBU with no cement returns to surface. POOH LD running tools. PU cleanout BHA. 3,212010 00 :00 - 3/23/2010 00:00 Operations Summary RIH with 4 -1/8" junk mill and cleanout BHA to 7,190'. CBU at 7,100' to 7,160' with green cement on returns. WOC. Dress off cement to 7,200'. Pumped clean FIW followed by chemical casing wash train. POOH LD BHA. 3/2 .!,'00:00.3/24/20140;00 :00 Operations Summary Continue POOH stand back 2 -7/8" DP and LD BHA. Test BOPE except for annular preventer to 200/3000 psi. Retest annular preventer to 200/1000 psi after changing cap seals and annular element. Perform accumulator drawdown test. Test witness waived by Jim Regg of AOGCC. RIH casing patch on wireline and tagged up at 5,755'. Attempt to work thru without success. Overpull 400 lbs to pull free. 2124/ 2010 00:00 - 3/25/2010 00 :007 , ; �� A ... , 41%,„ Operations Summary POOH with wireline and casing patch. PU 4 -1/8" stiff cleanout BHA and RIH to 5,656'. Wash and ream to 6,412' work thru 5,824' and 5,850' to 5,862' due to stall and torque increase. No signs of cuttings after CBU. POH and LD BHA components. RIH WL with 5.94 gage ring and junk basket to TOL at 5,472'. POOH. RIH with 3" gage ring to 7,195' WLM and tag cement. POOH. RIH WL with casing patch and tag up at 5,755'. Attempt to work thru without success. Overpull 600 lbs to pull free. 3. . ' 01000.00 - 3126/2010 00:00 Operations Summary POOH WL with casing patch. MU casing patch on DP and RIH. Abort running patch after meeting with asset and D &C management due to risk of prematurely setting at tight spot. POOH LD DP and casing patch. LD remainder of 2 -7/8" DP. /26/2010 00:00 - 3/27/2010 00:00 . ft Operations Summary LD 4 -3/4" DC and remainder of 3 -1/2" DP. PU and RIH with 3 -1/2" 9.2# L -80 completion assembly. 3/27/201000 :00. #0000 x {;: Operations Summary Continue PU and RIH with 3 -1/2" 9.2# L -80 completion assembly. MU tubing hanger and test control line to 5,000 psi. Pump and spot 25 bbls of 6% KCL corrosion inhibited packer fluid above the packer setting depth. Land tubing hanger with WLEG at 5,098' and production packer at 4,980'. Test tubing hanger seal void to 250/5000 psi for 5 minutes. Set packer with 4,000 psi in tubing for 15 minutes. Test packer set with 1,250 psi in annulus for 30 minutes. Set and left prong in X- Nipple plug body. ND BOPE. NU production tree and shell test to 250/5000 psi for 30 minutes. RD and prepare for leg move. Release rig at 24:OOH 3/27/2010. 3/21 M 1 R:1 = : 41112010 00 :00 `4 . :,. Operations Summary RU slickline, pressure test 250psi /2500psi high. Pull dummy valves from GLM's and replaced with live valves. (hewron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) M -17 TRADING BAY UNIT M -17 ADL017594; ADL018730 5073320552 LB2629 160.00 185.00 4/i42440,0040'.'412/2010 00:00 Operations Summary Unload fluid from the tubing. Retrieve prong and plug body from the X- Nipple at 4,867'. RD slickline. Fluid level at 4,837'. Shut in well with 750 psi in tubing. 4/512010 00 :00- 41612010 00:00 Operations Summary RU Eline, pressure test lubricator to 250psi low /3,000psi high. Perforate D14 sand at 7,142' - 7,155' thru- tubing with 6 spf using 2.5" guns. RD Eline. Turnover well to production for flow testing. Well flowing at 4.7 MMSCF at 1,316 psi. Chevron • •teelhead Platform "" 1%0 Well M -17 %. Recompleted 4/5/2010 CASING AND TUBING DETAIL SIZE WT GRADE CONN MIN ID TOP BTM RKB to TBG Head 71.82' (pp0 (in.) (MDrkb) 28" Structural 27 Surface 485' 13 -3/8" 68 L -80 BTC 12.415 Surface 895' 28" Conductor 9 -5/8" 40 L -80 BTC 8.835 Surface 1430' . ECP Stage Collar 7" 26 L -80 BTC -M 6.276 Surface 5700' . '/ 1 13 -3/8" in 17" Hole 5" liner 18 L -80 H513 4.180* 5472' 7637' ECP Stage Collar Tubing 3 -1/2" 9.2 L -80 TC -II (tube) 2.992 Surface 5098' 2 I (connection) 2.980 (drift) 2.867 Est TOC @ 920' *The 5 ", 18 #, FJ liner has an ID of 4.276" & a drift of 4.155 ". The H513 connection has a 4.194" machined pin ID. s The Baker ZXP Flex III hanger packer assemblyhas a TKC x H513 X over with a4.180" machined ID. This I- , 9 -5/8" in 12'/" Hol s 5" n Top Fish: Debris from 5" the drillable er. bridge plugs. Bottom represent Fish: the 2.5X15 ' Spira in l Jet EJ li gun, 1 11/16" x 1.5 firing head, 1 11/16" x 1.5' magnet, 4 1 11/16" x 1' CCL, 1 11/16" x 1' swivel, 1 11/16" x 18' weight bar, 1 3/8" x 22' rope socket. i i Perforation Detail MD Date Zone Density (SPF) Notes 5782 -5788 11 -29 -07 6 Squeezed, Ref SCMT Log 1 1/22/07 s 2 -15 ii2 1`)- , 8 i k ',rl,l,ezed. 1125 bilk 18. p1,.1 .I VI - 6 int f t 6234 -6 11 -2 7 -07 6 Squeezed, Ref SCMT Log 11/22/07 7 =. 7142 -7155 04 -05 -10 D14 6 SLB 2 -1/2" PJ Omega HC 60 phasing _ Plugged/Squeezed thru cement reta1nu 4 8 7213' with 3.25 bbls of LXT cement and 2 bbls dumped on top and dressed to 7200' i) ! k, Isolated with 5" Posi -Set Plug at 7423' and 15.25 gals (18') of dump bailed cement. 9 Miscellaneous Equipment Information 7" Casing ins' /:" Hole Item Depth OD ID Notes 11,4 13 3/8 x 28" ECP Stage Collar 454' Cemt'd to Surf 9 5/8 x 13 3/8 ECP Stage Collar 849' Attempt to Cemt to ML 1 SCSSV 426' 5.380" 2.813" Baker TE -5 2 GLM 4 1539' 5.968" 2.867" SFO -2 3 GLM 3 3192' 5.968" 2.867" SFO -2 4 GLM 2 4245' 5.968" 2.867" SFO -2 5 GLM 1 4914' 5.968" 2.867" SFO -2 6 Production Packer 4980' 5.97" 3.900" Baker S -3 7 X Profile Nipple 5040' 4.50" 2.813" Top of 8 WLEG (bottom) 5098' 3.93" 2.960" Primary Cement , 9 ZXP Flex III Hanger Packer 5472' 5.250" 4.180" is 7034' 10 5" Cement Retainer 7213' »» »» Top of Cement at 7200' D14 Zone • Top of Cement Plug at 7200' Cementing Information fo ' . Description Volume Dens Yield Notes . �' - : = DI6A Zone (syzd plugged) p r -r te, : r DI6C Zone (stud plugged) (bbls) (ppg) (ft3 /sx) 13 3/8 Stage 1 147 15.8 1.16 G GasBlok 1)17 Zone (plugged) 62 bbls Cement to Sur( G GasBok and 13 3/8 Stage 2 76 L, 188 T 15.8 1.17 G CaCI 5" Pon-Set plug at 7423 w/ 15.23 gals cmt placed w/ dump bailer (TOC 9 5/8 Stage 1 57 15.8 1.16 G GasBlok 5" Liner Shoe at 7637' tagged at 7405' ELM, 2 - 11 - 08) 9 5/8 Stage 2 32 15.8 1.17 G GasBlok, Cmt to surf 6 -1 /8" Hole TD at 7670' 7" Production 143 12.0 2.49 G LiteCrete 5" Liner Primary 49.5 15.8 1 2 G LXT, Partial to complete losses, MAX HOLE ANGLE' packed off. TOC @ 7034' per SCMT 5" Circ. Sqz, 6240' -5782' 16.5 15.8 1.2 G LXT, Partial to complete losses. 56.4° @ Tangent 2,796' MD 5" Balanced Plug across D3B and 21 15.8 1 21 G LXT, Partial returns, plug was old Sqz Perfs ineffective G LXT, down sqz thru cmt. ret., 1' plug 5" Sqz Plug across D3B (1" plug) 45 bbls 15 8 1 21 broke down at 1150 psi, 2 plug held (2 plug jobs) (2' plug) 46.5 bbls hydrostatic column, no surface pressure test 5" Downsqz thru cmt. retainer for 3.25 15.3 1.21 G LXT, down sqz thru cmt. ret. D16A and D16C 5" Cmt. Plug on top of retainer G LXT, dumped 2 bbls on top of above D16A and D16C 2 15.3 121 retainer and polished to 7200' Well Detail DRAWN BY: JAR 2/19/2008 Updated: 05/03/2010 RMS 1 T • a SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. Timothy C. Brandenburg Drilling Manager Union Oil Company of California a 2\-° P.O. Box 196247 a Y Anchorage, Alaska 99519 Re: McArthur River Field, Middle Kenai Gas Pool, Trading Bay Unit M -17 Sundry Number: 310 -044 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. 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, i Daniel T. Seamount, Jr. Chair DATED this ) `" day of February, 2010. Encl. wGA f s ., (9 ��`O RECEIVED/ilium STATE OF ALASKA FEB 1 6 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Alaska Oil & Gas Cans. Commission 20 AAC 25.280 Anchorage 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations IS . Perforate 0 • Pull Tubing El Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Fill cleanout El • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 ' Exploratory ❑ 207 -120 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 733 - 20552 -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 CI Trading Bay Unit M -17 ' 9. Property Designation (Lease Number): 10. Field / Pool(s): ` /�4 e ,-,. �L _ ii � b 1Je i ADL,017594, ADL018730 [Steelhead Platform] McArthur River Field / G ykng-ea555nds y /L i" 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): 7,670 6,380 7,405 6,149 7,405' 5,842' (511) Casing Length Size MD / TVD Burst Collapse Structural Conductor 485' 28" 485' 484' Surface 895' 13 -3/8" 895' 894' 5,020 psi 2,260 psi Intermediate 1,430' 9 -5/8" 1,430' 1,403' 5,750 psi 3,090 psi Production 5,700' 7" 5,700' 4,669' 7,240 psi 5,410 psi Liner 2,165' 5" 7,637' 6,350' 10,140 psi 10,500 psi Perforation Depth MD (ft): /Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,832' - 5,856', 7,296'- 7,308', 4,783'- 4,804', 6,052'- 6,062', 3-1/2" 9.2 #, L -80 5,472' 7,361'- 7,391', 7,456'- 7,470' 6,108' - 6,134', 6,191'- 6,203' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A / Baker TE -5 SSSV N/A / 439'MD (438'TVD) 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Development 0 ' Service ❑ 14. Estimated Date for . 3/21/2010 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas 0 . WDSPL ❑ Plugged ❑ 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 Ronnie Santos 263 -7978 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature C' _ one 276 -7600 Date 2/15/2010 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3,/,..4-0/-7 Plug Integrity ❑ / BOP Test (� Mechanical Integrity Test ❑ Location Clearance ❑ Other: T'e S L } LP t4QN 3op E L fc2 1000`) p S +. • T' esf' v& 't_ BopE -(-0 o 3o6o !a . Pw Zo AA-C. 2S. Z.45 (h), l�''e.v t 130 Pt is alp o Lie d. Subsequent Form Required: 10 — 4-0 4 . ' APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: 2//e//e Rt3DMS FEB 810 Form 10-403 Revised 12/2009 0 RIGNA L. Submit in D "` fP6 Chevron • • Trading Bay Unit %. Well # M -17 %. 2/11/10 OBJECTIVE: • Plug /isolate D3B, D16A, and D16C sands. Perforate D14, D13, and D6 sands (w/ contingency C5 sand). Zone isolation if lower zones would not produce PROCEDURE SUMMARY: 1 Displace well with FI 300'92 od 2 ND tree, NU BOP, same. 3 POOH w/ 3 1/2" ESP completion. 4 Cleanout fill from +/- 5,842' to PBTD +/- 7,405'. 5 Set 5" cement retainer at +1-7,245'. 6 Squeeze + 3,bbl cement below retainer. 7 Spot +/ 61 cement on top of retainer, pull up hole +/ -25' & circulate out excess cement. 8 Set compo . bridge plug at +/- 6,340'. 9 Pump +/ 5bb'1 cement plug and squeeze + / -5bbl into D3B (5,832'- 5,856') and old squeeze perfs (5782'- 5788' a 234'- 6240'). 7 , -- - , 10 Cleanout cement to +/- 6,315'. Pressure test liner to 1_25 si. 11 Conduct remedial block cement squeeze jobs if necessary until pressure test of 1250 psi is obtained. 12 Contingency to install a casing patch across D3B after multiple attempts of cement squeeze failures. / 13 Clean /drill out remaining cement & BP at +/- 6,340' down to top of cement plug at +/r6WPressure test liner to 1250 psi. L__.-- 14 Circulate hole clean and displace well with 6% KCL -FIW. 15 Run 3 -1/2" tubing gaslift completion to +/- 5,100', w/ production packer set at +/- 5,000'. 16 ND BOP, ND tree. 17 RU Eline. 18 Perforate and flow test D14 sand ( +/- 7,141'to +/- 7,154'). 19 RD Eline. Turn well over to production. Contingency (If insufficient production from D14, D13, or D6 sands.) 01 RU Eline. C2 Isolate non - productive intervals. C3 Recomplete, perforate and flow test well bottom up one zone at a time from D13 ( +/- 7,074' to +/- 7,080'), D6 ( +/- 6,169' to +/- 6,180'), and C5 ( +/- 5,148' to +/- 5,167') sands. C4 RD Eline. Turn well over to production. 4 1 Q ._,., 4, : ) .-1 t ii., i M -17 REVISED BY: RMS 2 -11 -10 ell M-17 Workover r DRAFT: Rev 1.1 r Prepared by: N orkover Planning Procedure Summary Date: Dec. 23, 28' Ronnie Santos Chevron Steelhead Platform Well M -17 1 As Built 2/19/08 CASING AND TUBING DETAIL RIyB to [BC. Lead -S.-5' SIZE %T GRADE CON.N MEN ID TOP BTIM _t (MDrkb) 28 structural 27 Surface 485' 28 toa�eeae 13-3,8"" 68 L-80 Bit 12,415 Surface 895' EcrStage ema 4 SB' 40 L-80 BTC 8.679 Surface 1430' 13 m 17 i' Role T 26 L -80 BTC -M 6.276 Surface 5700' 5" her 18 L-80 14513 4.1 ' 5472' 7637' - ECP %p a ase Tubing J 3-1/2 9.2 1.80 IBTM 2.99,2 Surface 5472' ' Est TOC on 920' The 5". 18 ppf. FJ liner has an ID of 42 76" and a drift of 4.155 ". The H513 connection has a 4.194" machined pin ID. L , 9-5/8 la 12 '.4" Hole The Baker ZXP Flex 111 hanger packer assembly has a TKC x H513 X over with a 4.180" machined ID. This represents the minimum ID in the 5" liner. Fish: 2.5X15' Spiral Jet EJ gun 1 11/16" x 1.5 firing head. 1 11/16" x 1.5' magnet. .--1 1 11116" x 1' CCL. 1 11f16" x 1' swivel. 1 11/16" x 18' weight bar. 1 3; 8 x 22" rope socket. Perforation Detail MD Date Zone Density (SPF) Notes 5148 -5167 Fimne C5 5782 -5788 11 -29 -07 6 Sgzd, Ref SCMT Log 11/22/07 1 ri C5 Zone 5832 -5856 02 -19-08 D3B 5 6169 -6130 Future 1)6 6234 -6240 11-27-07 6 Sgzd. Ref SCMT Log 11/22/07 7074-7080 Failure D1.3 Pr ° � e vr � le 7141 -7154 FLfuro D, 4 7296-7308 02-16-08 D -16A 6 -11 Ile -Shot 7298 -7308 5 SPF eannf ms +s H 1e 7361 -7391 02 -13-08 D 16C 6 11 Re-Shot 7361 -7381 5SPF 7 G 3 7 74567470 12 -21.08 D-17 11 D-17 Perfs (shot 2X, 63/5 SPF) Sgzd D38 Zone f Miscellaneous Equipment Informtion ui fo�md Fill e gge d at 5812 9 P 5780 " - Item Depth OD ID Notes 5920' D6 Zone 13 318 x29 ECP Static Collar 454 Cem'd to Surf and 6156' 9 Mx 13 3/8 ECP Stage Collar 849 Attempt to Cemt to ML 6240 Baker TES SCSSV 439 5.370 2.813 X Tubing Retrievable GLM4, SFO-2, R -2 VLV. RK 1807 5.968 2.867 GLM 3, SFO-2. R-2 VLV. RK 3738 5.968 2.867 Top of GLM 2, SKI-2, R -2 VLV. RK 4784 5.969 2.867 Prouty GM 1. SFO-2 (.250 Orifice) 5369 5.968 2.867 Cement D13 Zone X Profile Nipple 5426 3.973 2.813 X it iO34" D14 Zone 10' Locator sal Any 5472 5.250 4278 D16k Zone 1D160 Zone Cementing Information rem- s «os.°:ct". uII ea Description Volume Yield dotes sgaea +o s�n. e aq (JAW (ppt) (ft3 /sz1.17 ) d D17 Zest 13 318 Stage 1 147 15.15.8 8 1.16 G Gaslllat 13 3i8 Stage 2 76 L 188 T 62 bbls Cement to Surf, G 5 "L.er is 61 f Bak GasBok and G CaCI 9 518 Stage l 57 15.8 1.16 G GatBlok 9 5.41 Stage 2 32 15.8 1.17 G GaaBlok. Cent to unfit? T Production 143 12.0 2.49 G LiteCrrte 5" Lna Primary 49.5 15.8 1.2 G LXT, Partial to complete losses. packed off TOC 7034' per SCMT 5" Crentlation Sneeze 16.5 15.8 1.2 G LXT, Partial to complete 6240 -5782 losses. MAX HOLE ANGLE = 56.4° W Tangent 2,796' MD Well Detail DRAWN BY: JAR 2;19:08 Updated: 12;16,09 IthiS M -17 Workover Planning Procedure Summary Rev -1 -1- 20091223 (2).docx • Well M -17 Workove DRAFT: Rev 1.1 4 of 4 Workover Planning Procedure Summar Date: Dec. 23, 2009 Chevron Well e Platform %10. Well M -1-1 7 Proposed 2010 Workover RI{ i7TBG1Heai 78 .75' CASING AND TLJBLN DETAIL SIZE RT GRADE CONY LILY ID TOP BTC[ ' � (JIDrk6) 28" Struchrai 27" Surface 485' 2s Catar 13 -3i8" 68 L 80 BTC 12.415 Surface 895' ECP SraE Coav 9 -5+8 40 L-80 BTC 8.679 Surface 1430' 13 -34" in 17' ' Hole 7" 26 L -80 BTC -M 6.276 Surface 5700' I EC? Stage Collar 5 liner 18 L-80 H513 4.180 5472' 763T Tabu 3 -1.2" 0.2 L-80 Premium 2.992 Surface 5100' I Connection Est TOC , m 920' The 5 184t. FI Baer has an ID of 4.276° & a drift of 4.155 ". The 14513 connection has a 4.194 machined pin ID- The Baker ZXP Flex m hanger packer assembly has a TKC x H513 X over with a 4.180" machined ID. This I represents the rountnmm ID in the 5" hirer. ' 9 - 3 +t 12'.. Hole Proposed Fish: Debns from drillable bridge plug. Bottom Fish; 2.5X15' Spiral let EJ gun 1 1116" x 1.5 firing head- 1 11116" x 1.5' magnet, 1 1116` x 1 CCL 1 11.16" x 1' swivel, 1 11116 " x 18' weight bar. 1 3/8" x 22' rope socket. Perforation Detail I MD Date Zone Density (SPF) Notes 5148 -5167 Future C5 5782 -5788 11-29-07 6 Sqzd. Ref SCMT Log 11/22:07 5832 -5856 02 -19-08 D3B 5 ,- 6160 -6180 Proposed D6 d C 6234 -6240 11-27-07 6 Sqzd. Ref SCMT Log 11 Profile Nipple 7074.7030 Proposed D13 CS Zone (Fume) 7141 -7154 Proposed D14 7296 -7308 02 -16-08 D-16A 6-11 Re -Shot 7298 -7308 5 SPF 7361 -7391 02 -13-08 D -16C 6-11 Re -Shot 7361 -7381 5SPF 7456 -7470 12 -21-08 D-17 11 D-17 Perfs (shot 2X, 6&5 SPF) Miscellaneous Equipment Information Item Depth OD ID Notes 7cmogul e5: - tide 13343 x 28`ECP Stage Collar 454 Cent'd to Surf 9 51 x 13 343 ECP Stage Collar 849 Attempt to Cemt to ML n td not DID Zane (to be and plugged) ZXP Flex III Hanger Packer 5472 5.250 4.180 •a and at SCSSV - 439 1370 1.313 X Proposed s. to - GLtd4, SFO-? -1807 5.068 2.367 Proposed WM D6 Zoe. (Proposal and - GLN 3, 3F0-2 -3733 5.968 2.867 Proposed 6156'- GL142, SFO-2 -4734 5.968 2.367 Proposed 62 Glie1, SF0-2 -4937 5.968 2.867 Proposed Production Packer -5000 .Proposed XProftle Fipple -5063 3.973 2.813 X Proposed T� KEG (bottom -50' from C5) -5100 Proposed C 013 Zoos (Amami/ Cementing Information (Prior to this Proposed Workover) 11 7034 DI Zone(Ropooed) Description Vohrme Dens Yield Notes 1 Z L1 S (bbls) (ppt[) (ft3 /1x) D16A Zone (0be 13 318 Stage 1 147 15.8 1.16 GGasBk lo D16C Zama On sad a►+Qedt 13 318 Stage 2 76 L.188 T 15.8 1.17 62 bbls Cement to Surf, G GasBok and G Coe! Ea DI7 Zane 9 5 Stage 1 57 15.8 1.16 G GasHlok tweaetaa r: t152.3 epia c 9 518 Stage 2 32 15.8 1.17 G GasIlok, Cmt to surf?!? � � 1-00 S boor m 6 l�9' Hole wM ■1an'traquatal 7 Production 143 12.0 2.49 GLiteCtete 5" Liner Primary 49.5 15.8 1.2 G LXT, Partial to complete losses, packed off. TOC @ 7034' per SCMT 5" Circulation Sgeere 16.5 15.8 1.2 G INT. Partial to complete 6240 -5782 losses. MAX HOLE ANGLE = 56.4 C Tangent 2,796' MID Well Detail DRAWN BY: JAR 2/19/08 Updated: 12%17/09 RMS M -17 Workover Planning Procedure Summary Rev -1 -1- 20091223 (2).docx 1 • M -17 Workover 20 -3/4" BOP / Diverter Stack Up 21 114" 2M Hydril Annular 4.22' HUB CLAMP 20 3/4" 3 M Hydril DBL Gate Pipe Rams 4.71' 20 3/4" 3M Blind Rams HUB CLAMP 20 3/4" 3M Mud Cr 2.00' oss _ rmi HCR HUB CLAMP 20 3/4" 3M Single Gate 2.71' HUB CLAMP 2 ea, 16" Ansi 600 Diverter Valves 20 314 3M 2.00 NT2 Connector XO Diverter Spool 3.00' 20 3/4 3M NT2 /• Connector 20 314" 3M Riser I I I I 20 -3/4" 3M Spacer Spool P P 13 -5/8" 5M x 20 -3/4" 3M DSA VETCO MB -220 Tbg Head Flange 13 -5/8" 5M 1 I Page 1 of 2 • Maunder, Thomas E (DOA) From: Rose, Jim [Contractor] [RoseJi @chevron.com] Sent: Tuesday, July 01, 2008 7:14 AM To: Maunder, Thomas E (DOA) Subject: RE: TBU M -17 (207 -120) ok, works for me From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, July 01, 2008 6:59 AM To: Rose, Jim [Contractor]; Greenstein, Larry P Cc: Davies, Stephen F (DOA) Subject: RE: TBU M -17 (207 -120) Jim and Larry, Have a look at definition (14) in our regulations 20 AAC 25.990. The well was flowed and it appears that produced fluids were "sold" from that first set of perfs. It is unfortunate that the initial completion zone(s) were not as successful as the subsequent zones. Marathon has had a couple of wells that required a lot more work to ultimately be economical and it took them over a year, however the date used as the official completion date was when first shot. Call or message with any questions. Tom Maunder, PE AOGCC From: Rose, Jim [Contractor] [mailto:RoseJi @chevron.com] Sent: Tuesday, July 01, 2008 6:51 AM To: Maunder, Thomas E (DOA); Greenstein, Larry P Subject: RE: TBU M -17 (207 -120) Tom I am not very familiar with the definitions used for completion dates and such. If the first perfs in a well prove to be uneconomical and the well is ultimately recompleted to another zone, is the first attempt considered a test or a completion? In my mind, the date of completion is the date that economical production is established. Please advise. Jim From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, June 30, 2008 2:40 PM To: Rose, Jim [Contractor]; Greenstein, Larry P Subject: TBU M -17 (207 -120) Jim and Larry, Not sure which of you should get this message and it should like be forwarded on. I have completed review of the 407 for TBU M -17. Jim recently got me the greater detailed operations summary. Anyhow, on the 407 the completion date is listed as 2/19/2008 which appears to be when all the well work was completed. However, there are 2 days of production reported (in our 7/1/2008 • Page 2 of 2 • record) in December. Looking at the summary, it appears that the initial perfs were shot on 12/21/07 and the well was flowed on 12/29. 12/29 is the date we consider the well completed. As I said, I am not sure this is something you will handle but I'll bet you know who will. Call or message with any questions. Tom Maunder, PE AOGCC 7/1/2008 Page 1 of 1 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, June 30, 2008 2:40 PM To: 'Rose, Jim [Contractor]'; Larry Greenstein Subject: TBU M -17 (207 -120) Jim and Larry, Not sure which of you should get this message and it should like be forwarded on. I have completed review of the 407 for TBU M -17. Jim recently got me the greater detailed operations summary. Anyhow, on the 407 the completion date is listed as 2/19/2008 which appears to be when all the well work was completed. However, there are 2 days of production reported (in our record) in December. Looking at the summary, it appears that the initial perfs were shot on 12/21/07 and the well was flowed on 12/29. 12/29 is the date we consider the well completed. As I said, I am not sure this is something you will handle but I'll bet you know who will. Call or message with any questions. Tom Maunder, PE AOGCC I I 6/30/2008 • Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, June 25, 2008 8:15 AM To: 'Rose, Jim [Contractorj' Subject: RE: TBU M -17 (207 -120) Thanks Jim, this should be just what I need. Tom From: Rose, Jim [Contractor] [mailto:RoseJi @chevron.com] Sent: Wednesday, June 25, 2008 8:11 AM To: Maunder, Thomas E (DOA) Subject: RE: TBU M -17 (207 -120) Tom I V‘str\ \-4 :0 ' ) fir\ please see the attached operational time detail for M -17. let me know if you need anything else Jim From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, May 23, 2008 1:11 PM To: Rose, Jim - Contractor Cc: Brandenburg, Tim C Subject: TBU M -17 (207 -120) Jim, I am catching up on reviewing completion reports. Could you please provide operations reports with greater detail? The submitted reports do not have enough detail for me to effectively review. What I really need is the hourly. I know it may be a lot of pages, but it is what I need to do my work. Email is fine. Call or message with any questions. Tom Maunder, PE AOGCC 7/1/2008 Chevron I ncisco Castro Chevron North •rica Exploration and Production *,:, Technical Assistant 909 W. 9th Avenue � Anchorage, AK 99501 ft Tele: 907 263 7844 Fax: 907 263 7828 E -mail: fcbn @chevron.com DATE June 9, 2008 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL }x e. ■ tt -13-9 COMPLETION TB ST A -25RD RECORD 5" 4- Mar -08 6660 -7092 1 1 1 PDS /4 ,, , q04/ i `30 — /e /9„. COMPLETION .- TBSTA -01RD RECORD 5" 5- Mar -08 5697 -6140 1 1 PDS ��< /O5 )01-0- COMPLETION � C TBU K -18RD RECORD 5" 21- Feb -08 10800 -12400 1 1 PDS COMPLETION _I&cla TBU K -26 RD RECORD 5" 24- Feb -08 10303 -10323 1 1 PDS J C i96"C5dSo PERFORATING / (oC(O'6 TBU G -22 RECORD 5" 3- May -08 10122 -10229 PS -2 1 1 DLIS -PDS PERFORATING TBU M -17 RECORD 5" 16- Feb -08 7298 -7381 PS -11 1 1 PDS )0r 0O PERFORATING TBU M -17 RECORD 5" 14- Feb -08 7296 -7391 PS -9 1 1 PDS /(off ° POSISET PLUG 1via i SETTING /c9Q TBU M -17 RECORD 5" 11- Feb -08 6889 -7430 PS -8 1 1 PDS PRESSURE TEMPERATURE TBU M -17 LOG 5" 15- Feb -08 5636 -7398 PS -10 1 1 PDS DEPTH TBU M -17 DETERMINATION 5" 3- Feb -08 5782 - 7374.5 PS -7 1 1 PDS PERFORATING TBU M -17 RECORD 5" 19- Feb -08 5832 -5856 PS -12 1 1 PDS POSISET PLUG /'$9 -0 SETTING TBU M -01 RECORD 5" 7- Jan -08 4792 -5151 PS -2 1 PDS / 450 fr PERFORATING / 40 TBU M -01 RECORD 5" 18- Jan -08 4532 -4580 PS -3 1 PDS ,)-d - 10 3 HAPPY CEMENT BOND PDS, LAS, VALLEY B -12 LOG - SCMT 5" 18- Mar -08 3559 -10315 1 1 1 DLIS 7O/ a /( COMPLETION PDS, DLIS, / (,y/!a _ LRU C -01 RD RECORD 5" 14- May -08 4679 -4759 1 1 FMA PERFOION / 414 " 1r14 I SRU 32A -15 I SHOOT RECORD 15" 110- Mar -08 1 5554 -5582 1 I 1 I PDS / ��ir Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received 8,y3 4 1 7/ Date: Chevron Frasco Castro Chevron North Am ./a Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 *4° Tele: 907 263 7844 Fax: 907 263 7828 E -mail: fcbn @chevron.com DATE April 3, 2008 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste# 100 Anchorage, AK 99501 DATA TRANSMITTA x, x 4`S``�':' '� OTES F 3 . k 4 INTERVAL. COG DATE �.� � � YT SAS PDS �� LOGED' ® LIS 27- Oct -07 401 -7700 MUDLOG, 6.125 in HOLE LOG, 8.5 in HOLE 4- Nov -07 500 -1382 TBU M -17 LOG, 17.5 12.25 in HOLE LOG 12- Nov -07 485 -1435 1 LAS 20- Nov -07 1400 -5712 12- Dec -07 5700 -7670 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By y, / Date: 4116--/0 • 0 Chevron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK 99519 -6247 %. Tel 907 263 7657 Fax 263 Emmail il brandenburgt@chevron.com March 6, 2008 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7 Avenue Anchorage, Alaska 99501 Re: McArthur River Field, Steelhead M -17, PTD 207 -120, API No. 50- 733 - 2052 -00 Dear Commissioner, Attached please find the data required by 20 AAC 25.070 for the above referenced well. Some of the geologic data required by 20 AAC 25.071 has already been submitted. The remaining geologic data will be submitted as soon as it becomes available. Please contact Jim Rose at 907 - 263 -7637 if you have any questions regarding this information. Sincerely, /-� __ _ Timothy C. Brandenburg 4 Drilling Manager TCB: sk Attachment: Form 10-407 Completed Well Sketch Formation Tops Wellbore Survey Daily Operations Summary M -17 Mud Density -v- Depth Chart Cc: File Union Oil Company of California / A Chevron Company Page 1 of 1 .yes NCV = I v L.. • STATE OF ALASKA ..rlirr MAR 1 1 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION W ELL COMPLETION OR RECOMPLETION REP A ' mmlss la. Well Status: Oil ❑ Gas 0 Plugged ❑ Abandoned ❑ Suspended ❑ lb. Well ClassAfwlr age 20AAC 25.105 2OAAC 25.110 Development 0 Exploratory❑ GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other❑ No. of Completions: Service ❑ Stratigraphic Test❑ 2. Operator Name: 5. Date omp , Susp., or ll�"' 4 12. Permit to Drill Number: 11 Union Oil Company of California Mo'de , 2(.1.W26O8' 207 -120 - 1 �% � -- 3' S L 6 3. Address: 6. Date S ed: - 7' ` ' 13. API Nuc ;>ss� • PO Box 196247, Anchorage, AK 99519 10/27/2007 / 50- 733- P952 -00 4//-idr 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1052' FNL 455' FWL, SEC 33 T9N, R13W, SM 11/16/2007 / Steelhead M -17 Top of Productive Horizon: 8. KB (ft above MSL): 160 / 15. Field /Pool(s): 3809' FNL 204' FEL, SEC 32 T9N, R13W, SM Ground (ft MSL): McArthur River, GGS' Total Depth: 9. Plug Back Depth(MD +TVD): Middle Kenai Sands 4712' FNL 321' FEL, SEC 32 T9N, R13W, SM 7405' - 6149 ' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 214070 y- 2499450 Zone- 4 7670' -6380' ADL- 17594, ADL -18730 TPI: x- 213429 y- 2496699 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 213204 y- 2495811 Zone- 4 439' - 439' 18. Directional Survey: Yes 12 No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) 185 (ft MSL) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): Gamma Ray /Resitivity /Density Neutron/ Magnetic Resonance/ Cement Evaluation 22. 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 28 -32 0.5 -1" WT X -56 Surf 485 Surf 485 Drvn 13 3/8 68 L -80 Surf 895 Surf 894 17 1/2 411 bbls G 9 5/8 40 L -80 Surf 1430 Surf 1403 12 1/4 89 bbls G 7 26 L -80 Surf 5700 Surf 4669 8 1/2 143 bbls G 5 18 L -80 5472 7637 4471 6350 6 1/8 49.5 bbls G, 16.5 bbls G Sqz 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) 3 1/2 5472 NA 5832 -5856 (4783 -4804 TVD), 5 SPF 7296 -7308 (6052 -6062 TVD), 11 SPF 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7361 -7391 (6108-6134 TVD), 11 SPF DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 5782 -6240 16.5 bbls Class G Circulation Sqz 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 2/19/2008 Flowing Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 2/22/2008 24 Test Period -.). 0 6060 2 NA NA Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 746 0 24 -Hour Rate 0 6060 2 NA 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No el Sidewall Cores Acquired? Yes ❑ No El j 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. z.,Gd i J ; �( , 4 -v . Form 10-407 Revised 2/2007 CONTINUED ON REVERSE R( 3( 0,) O � °" , , 2 (, J 1 • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD 1 TVD Well tested? 0 Yes ❑ No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if See attached Formation Tops needed, and submit detailed test information per 20 AAC 25.071. Spreadsheet GGS D -17, Gas and Water, Abandoned GGS D -16A, D16C Gas GGS D -3B, Dry Gas Formation at total depth: 30. List of Attachments: Well Sketch, Final Survey, Formation Tops, Operations Summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jim Rose, 907 - 263 -7637 Printed Name: Timothy Brandenburg Title: Drilling Manager ^� Signature: Phone: 907 - 276 -7600 Date: 3 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 la: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for / 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 • •eelhead Platform , Iwo Well M -17 %. As Built 1/9/07 CASING AND TUBING DETAIL RKB to TBG Head = 78'75.00' SIZE WT GRADE CONN MIN ID TOP BTM (MDrkb) { 28" Structural 27" Surface 485' JR. 28" Conductor 13 -3/8" 68 L -80 BTC 12.415 Surface 895' ECP Stage Collar 9 -5/8" 40 L -80 BTC 8.679 Surface 1430' NIL 13-3/8" in 17 r" Hole 7" 26 L -80 BTC -M 6.276 Surface 5700' ' 41 a ECP Stage Collar 5" liner 18 L -80 H513 4.194* 5472' 7637' Tubing 3 -1/2" 9.2 L -80 IBTM 2.992 Surface 5472' Est TOC @ 920' The 5 ", 18 ppf, FJ liner has an ID of 4.276" and a drift of 4.155 ". The H513 connection has a 4.194" machined pin ID. 9 -5 /8" in 12'/." Hole The Baker ZXP Flex III hanger packer assembly has a TKC x H513 X over with a 4.180" machined ID. This represents the minimum ID in the 5" liner. Fish: 2.5X15' Spiral Jet EJ gun, 1 11/16" x 1.5 firing head, 1 11/16" x 1.5' magnet, 1 11/16" x 1' CCL, 1 11/16" x 1' swivel, 1 11/16" x 18' weight bar, 1 3/8" x 22' rope socket. Perforation Detail MD Zone Density (SPF) Notes 5782 -5788 6 Sqzd, Ref SCMT Log 11/22/07 6234 -6240 6 Sqzd, Ref SCMT Log 11/22/07 5832 -5856 D3B 5 Profile Nipple 7296 -7308 D -16A 6 -11 Re -Shot 7298 -7308 5 SPF 7361 -7391 D -16C 6 -11 Re -Shot 7361 -7381 5SPF 7" Casing in 8 '/a" Hole 7456 -7470 D -17 11 D -17 Perfs (shot 2X, 6 &5 SPF) Miscellaneous Equipment Informtion . Item Depth OD ID Notes 13 3/8 x 28" ECP Stage Collar 454 Cem'd to Surf 9 5/8 x 13 3/8 ECP Stage Collar 849 Attempt to Cemt to ML Baker TE5 SCSSV 439 5.370 2.813 X Tubin. Retrievable GLM 4, SFO-2, R -2 VLV, RK 1807 5.968 2.867 GLM 3, SFO-2, R -2 VLV, RK 3738 5.968 2.867 GLM 2, SFO-2, R -2 VLV, RK 4784 5.968 2.867 GLM 1, SFO-2 (.250 Orifice) 5369 5.968 2.867 X Profile Nipple 5426 3.973 2.813 X 10' Locator Seal Assy 5472 5.250 4.278 Top of Primary Cement is 7034" Cementing Information Description Volume Dens Yield Notes di 5" Posi -Set plug at 7423' w/ 15.23 gals cmt placed w/ (bbls) (ppg) (ft3 /sx) dump bailer (TOC tagged at 13 3/8 Stage 1 147 15.8 1.16 G GasBlok 7405' ELM) 13 3/8 Stage 2 76 L, 188 T 15.8 1.17 62 bbls Cement to Surf; G GasBok and G CaC1 5" Linerin6 1/8" Hole 9 5/8 Stage 1 57 15.8 1.16 G GasBlok 9 5/8 Stage 2 32 15.8 1.17 G GasBlok, Cmt to surf?!? 7" Production 143 12.0 2.49 G LiteCrete 5" Liner Primary 49.5 15.8 1.2 G LXT, Partial to complete losses, packed off. TOC @ 7034' per SCMT 5" Circulation Sqeeze 16.5 15.8 1.2 G LXT, Partial to complete 6240 -5782 losses. MAX HOLE ANGLE = 56.4° @ Tangent 2,796' MD Well Detail DRAWN BY: JAR 1/9/07 Steelhead M -17 Formation Tops API No: 50- 733 - 2052 -00 APD: 207 -120 Well Surface ft MDbrf ft TVDbrf ft TVDss Well Surface ft MDbrf ft TVDbrf ft TVDss M -17 Shoe28 490.26 490 -330 M -17 SZ14CT 1936.79 1835 -1675 M -17 SZOCT 799.22 799 -639 M -17 SZ14CB 1946.71 1843 -1683 M -17 SZOCB 803.31 803 -643 M -17 SZ15ST 1979.59 1868 -1708 M -17 SZ1 CT 855.34 855 -695 M -17 SZ15CT 2017.79 1897 -1737 M -17 13.325" SHOE 895 894 -735 M -17 SZ16ST 2039.09 1913 -1753 M -17 SZ2CT 945.52 945 -785 M -17 SZ16SB 2231.43 2049 -1889 M -17 SZ3CT 989.73 989 -829 M -17 SZ16CT 2231.43 2049 -1889 . M -17 SZ4CT 1046.27 1045 -885 M -17 SZ16CT 2237.44 2053 -1893 M -17 SZ4CB 1069.61 1068 -908 M -17 SZ16CB 2262.25 2069 -1909 M -17 SZ5ST 1083.98 1082 -922 M -17 SZ17ST 2296.07 2091 -1931 M -17 SZOCT 1129.25 1126 -966 M -17 SZ17SB 2341 2120 -1960 M -17 SZOCB 1132.4 1129 -969 M -17 SZ17CT 2382.04 2145 -1985 M -17 SZ6ST 1158.25 1154 -994 M -17 SZ17CB 2388.86 2149 -1989 M -17 SZ6SB 1210.08 1203 -1043 M -17 SZ18CT 2549.44 2241 -2081 M -17 SZ6CT 1226.77 1219 -1059 M -17 SZ18CB 2575.22 2255 -2095 M -17 SZ6CB 1239.76 1231 -1071 M -17 SZ19CT 2665.9 2306 -2146 M -17 SZ7SB 1267.1 1256 -1096 M -17 SZ19CB 2673.5 2310 -2150 M -17 SZ7CT 1279.08 1267 -1107 M -17 SZ19STRYT 2709.62 2330 -2170 M -17 SZ7CB 1293.5 1280 -1120 M -17 SZ19STRYB 2729.44 2341 -2181 M -17 SZ8ST 1313.06 1298 -1138 M -17 SZ20ST 2743.99 2349 -2189 M -17 SZ8SB 1333.99 1317 -1157 M -17 SZ20SB 2756.53 2356 -2196 M -17 SZOCT 1351.5 1333 -1173 M -17 SZ20CT 2798.15 2379 -2219 M -17 SZOCB 1359.24 1340 -1180 M -17 SZ20CB 2807.62 2384 -2224 • M -17 9.625" SHOE 1430 1403 -1244 M -17 SZ21ST 2830.44 2397 -2237 M -17 SZ10CT 1492.13 1459 -1299 M -17 SZ21SB 2927.37 2450 -2290 M -17 SZIOCB 1521.49 1485 -1325 M -17 SZ21CT 2978.93 2479 -2319 M -17 SZIIBST 1585.51 1542 -1382 M -17 SZ21CB 2995.71 2488 -2328 M -17 SZ11CT 1680.68 1624 -1464 M -17 SZ22ST 3010.03 2496 -2336 M -17 SZ11CB 1695.88 1637 -1477 M -17 SZ22SB 3044.45 2515 -2355 M -17 SZ12ST 1709.36 1649 -1489 M -17 SZ22CT 3057.62 2523 -2363 M -17 SZ12SB 1756.76 1689 -1529 M -17 SZ22CB 3083.97 2537 -2377 M -17 SZ12CT 1768.74 1699 -1539 M -17 SZ23AST 3090.5 2541 -2381 M -17 SZ12CB 1789.45 1716 -1556 M -17 SZ23ASB 3109.83 2552 -2392 M -17 SZ13ST 1807.98 1731 -1571 M -17 SZ23BST 3164.68 2583 -2423 - M -17 SZ13CT 1858.48 1773 -1613 M -17 SZ23BSB 3248.27 2633 -2473 M -17 SZ13CB 1861.13 1775 -1615 M -17 SZ23BCT 3252.39 2635 -2475 M -17 SZ14SB 1936.77 1835 -1675 M -17 SZ23BCB 3258.7 2639 -2479 Page 1 of 3 Steelhead M -17 Formation Tops API No: 50- 733 - 2052 -00 APD: 207 -120 Well Surface ft MDbrf ft TVDbrf ft TVDss Well Surface ft MDbrf ft TVDbrf ft TVDss M -17 ACT 3285.89 2656 -2496 M -17 B5CT 4617.18 3730 -3570 M -17 ACB 3298.51 2664 -2504 M -17 B5CB 4631.22 3742 -3582 M -17 Al CT 3361.97 2704 -2544 M -17 B7STRT 4665.93 3772 -3612 M -17 A2ST 3386.25 2720 -2560 M -17 B7STRB 4703.88 3805 -3645 M -17 A2SB 3499.25 2797 -2637 M -17 CCT 4796.65 3885 -3725 M -17 A2CT 3505.12 2801 -2641 M -17 CCB 4816.41 3902 -3742 M -17 A2CB 3529.74 2819 -2659 M -17 C1ST 4843.72 3926 -3766 • M -17 A2ASB 3555.88 2837 -2677 M -17 C1SB 4894.32 3970 -3810 M -17 A3SB 3635.14 2897 -2737 M -17 C1CT 4938.09 4008 -3848 M -17 A4CT 3685.86 2936 -2776 M -17 C2CT 4956.94 4024 -3864 M -17 ASST 3708.73 2954 -2794 M -17 C3ST 4971.16 4036 -3876 M -17 A5BST 3744.04 2982 -2822 M -17 C3SB 5034.13 4091 -3931 M -17 A5CST 3779.56 3010 -2850 M -17 C4ST 5050.12 4105 -3945 M -17 A5CT 3832.89 3054 -2894 M -17 C4SB 5099.32 4147 -3987 M -17 A6ST 3872.25 3087 -2927 M -17 C3CT 5115.15 4161 -4001 M -17 A6SB 3911.5 3120 -2960 M -17 C5ST 5147.88 4190 -4030 M -17 BCT 4006.35 3201 -3041 M -17 C5SB 5170.44 4209 -4049 M -17 BCB 4033.39 3224 -3064 M -17 C7ST 5230.92 4262 -4102 M -17 B2ST 4102.36 3284 -3124 M -17 C7SB 5236.88 4267 -4107 M -17 B1 CT 4165.86 3339 -3179 M -17 DCT 5244.91 4274 -4114 M -17 B1 CB 4172.52 3344 -3184 M -17 DCB 5261.71 4288 -4128 M -17 B3SB 4268.36 3428 -3268 M -17 D1 ST 5281 4305 -4145 M -17 B4ST 4286.35 3443 -3283 M -17 D1strayT 5282.74 4307 -4147 0 M -17 B4SB 4345.35 3494 -3334 M -17 D1 strayB 5315.99 4335 -4175 M -17 B4AST 4372.2 3517 -3357 M -17 D1SB 5581.71 4566 -4406 M -17 B4ASB 4376.89 3522 -3362 M -17 D1 CT 5585.7 4570 -4410 M -17 B2CT 4380.72 3525 -3365 M -17 D1CB 5628.13 4606 -4446 M -17 B2CB 4394.76 3537 -3377 M -17 D2ST 5652.63 4628 -4468 M -17 B3CT 4401.26 3543 -3383 M -17 D2SB 5692.4 4662 -4502 M -17 B3CB 4419.59 3559 -3399 M -17 7" SHOE 5700 4669 -4509 M -17 B5ST 4441.23 3577 -3417 M -17 D2CT 5753.43 4715 -4555 M -17 B4CT 4512.41 3639 -3479 M -17 D2CB 5783.91 4742 -4582 M -17 B4CB 4519.11 3645 -3485 M -17 D2ACT 5810.41 4765 -4605 M -17 B6ST 4535.75 3659 -3499 M -17 D2ACB 5819.74 4773 -4613 Page 2 of 3 Steelhead M -17 Formation Tops API No: 50- 733 - 2052 -00 APD: 207 -120 Well Surface ft MDbrf ft TVDbrf ft TVDss Well Surface ft MDbrf ft TVDbrf ft TVDss M -17 D3BST 5826 4778 -4618 M -17 D14CT 7209.43 5977 -5817 M -17 D3BSB 5858.61 4807 -4647 M -17 D14CB 7220.76 5987 -5827 M -17 D3CT 5968.17 4902 -4742 M -17 D15CT 7280.83 6039 -5879 M -17 D3CB 5989.4 4921 -4761 M -17 D15CB 7290.83 6047 -5887 1 M -17 D4CT 6107.34 5024 -4864 M -17 D16AST 7293.79 6050 -5890 M -17 D4CB 6127.21 5041 -4881 M -17 D16ASB 7307.43 6062 -5902 M -17 D5CT 6140.46 5053 -4893 M -17 D16BST 7334 6085 -5925 • M -17 D5CB 6159.05 5069 -4909 M -17 D16BSB 7342 6092 -5932 M -17 D6ST 6169 5078 -4918 M -17 D16CST 7355.17 6103 -5943 M -17 D6SB 6194.21 5100 -4940 M -17 D16CSB 7389.63 6133 -5973 M -17 D6CT 6245.3 5144 -4984 M -17 D16CT 7438.46 6176 -6016 M -17 D6CB 6257.15 5155 -4995 M -17 D16CB 7449.67 6186 -6026 M -17 D7CT 6315.45 5205 -5045 M -17 D17ST 7452.57 6188 -6028 M -17 D7CB 6319.44 5209 -5049 M -17 D17SB 7529.48 6256 -6096 M -17 D8ST 6331.67 5219 -5059 M -17 D17CT 7532.52 6258 -6098 M -17 D8SB 6421.3 5298 -5138 M -17 D17CB 7541.73 6266 -6106 M -17 D8CT 6482.31 5351 -5191 M -17 D18ST 7546.55 6271 -6111 M -17 D8CB 6486.24 5354 -5194 M -17 ECT 7598.27 6316 -6156 M -17 D9ST 6533.25 5395 -5235 M -17 ECB 7606.76 6324 -6164 M -17 D9SB 6614.44 5465 -5305 M -17 5" Shoe 7637 6350 -6190 M -17 D9CT 6655.76 5501 -5341 M -17 TD 7670 6379 -6219 M -17 D9CB 6659.75 5504 -5344 M -17 D10ST 6673 5516 -5356 0 M -17 D10SB 6809.23 5634 -5474 M -17 D10CB 6819.21 5642 -5482 M -17 D11CT 6869.06 5685 -5525 M -17 D11CB 6876.48 5691 -5531 M -17 D12ST 6899.5 5711 -5551 M -17 D12AST 6933.26 5740 -5580 M -17 D12CT 6995.24 5793 -5633 M -17 D12CB 7012.17 5807 -5647 M -17 D13ST 7064.87 5852 -5692 M -17 D13SB 7096.51 5880 -5720 M -17 D13CT 7101.21 5884 -5724 :M -17 D13CB 7105.25 5887 -5727 M -17 D14ST 7131.39 5910 -5750 M -17 D14SB 7155.47 5930 -5770 Page 3 of 3 a • 0 , Chevron EOM Actual Wellpath Report BAKER too SDI Gyro - Keeper <78-1391'>ATK G3 MWD<1482 - 5666'>OnTrak MWD<5 HUGHES Page 1 of 5 INTEQ REFERENCE WELLPATH IDENTIFICATION .., _ Operator ■Chevron Slot I slot #A1-9 i !Area Cook Inlet, Alaska (Offshore) Well 1111-17 1 r -- Tield McArthur River Field Wellbore I-17 1 --- 'Facility STEELHEAD Platform 1 REPORT SETUP INFORMATION 'Projection System NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Software System WellArchitect® 2.0 [North Reference True , User Ulricard ,Scale 0.999993 Report Generated 1/11/2008 at 9:35:42 AM Convergence at slot 1.40° West Database/Source file WA_Anchorage/M-17.xml L,..._ WELLPATH LOCATION 1 i ,---- 1 --- 1 Local coordinates Grid coordinates I Geographic coordinates I 1 North[ft] 1 EastIft] Easting[USft] Northing[USft] , Latitude , Longitude , Slot Location -1052.80 45534 214070.16 2499450.47 60 151°3608.833"W Facility Reference Pt I 213640.71 2500514.08 , 60°50'04.803"N I 151°36'18.018"W 1 ,— Field R r eference Pt I 213640.71 2500514.08 60°50'04.803"N 151°36'18.018"W i WELLPATH DATUM i Actual Datum (RKB) to Facility Vertical Calculation method Minimum curvature 1 160.25ft Datum Horizontal Reference Pt 1NW Corner of Sec. 33, T9N, R13W SM Actual Datum (RKB) to mean sea level L16025 ,Vertical Reference Pt rik Datum (RKB) Facility Vertical Datum to Mud Line (Facility) 0 OOft f IMD Reference Pt l Actual Datum (RKB) Section Origin N -1052.80, E 455 34 ft Field Vertical Reference mean sea level Section Azimuth [192.38° . • Chevron MINI tolli Actual Wellpath Report BAKER SDI Gyro - Keeper <78- 1391' >ATK G3 MWD <1482 - 5666' >OnTrak MWD <5 HUGHES Page 2 of 5 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator i Chevron `Slot slot #A1 - Area Cook Inlet, Alaska (Offshore) Well M - 17 [ield McArthur River Field Wellbore M -17 Facility STEELHEAD Platform WELLPATH DATA (98 stations) 1' = interpolated /extrapolated station MD Inclination Azimuth TVD TVD from Vert Sect North East Grid East Grid North DLS [ft] [ ° l 11 [ft] Fld Vert Ref IN [ft] [ft] [sry ft] [sry ft] 1 ° /100ft] ! [ftl - 0.00 0.000 0.00 - 160.25 0.00 - 1052.80 455.34 214070.16 2499450.47 0.00 - 78.00 0.000 192.740 78.00 -82.25 0.00 - 1052.80 455.34 214070.16 2499450.47 0.00 - 128.00 1 0.180 1 128.00 -32.25 0.08 - 1052.88 455.32 214070.14 2499450.39 0.36: 178.00 0.090 97.380 178.00 17.75 0.15 - 1052.96 455.34 214070.16: 2499450.31 0.42 228.00 0.180 133.070 228.00 67.75 0.19 - 1053.02 455.44 _ 2141 I * ° * SQ 0.24 1 278.00 0.000 0.000 278.00 117.75 0.23 - 1053.07 1 455.50 ' 214070.31 2499450.19 0.36 328.00 0.090 134.650 328.00 167.75 0.25 - 1053.10 455.53 . 214070.34 2499450.16 0.18 378.00 0.180 162.330 378.00 217.75 0.34 - 1053.20 h' 455.58 214070.39 2499450.06 0.22 428.00 0.350 200.480 428.00 267.75 0.56 - 1053.42 455.55 214070.35 2499449.84 0.47 478.00 0.620 197.930 478.00 317.75 0.98 - 1053.82 455.41 214070.20 2499449.45 `" 0.54 528.00 0.790 197.310 527.99 367.74 1.59 - 1054.41 455.23 214070.00 2499448.86 0.34 1 578.00 0.620 203.9901 577.99 417.74 2.20 - 1054.98 455.01 214069.78 2499448.29 0.38 _ 628.00 0.790 217.620 627.99 467.74 2.78 - 1055.50 454.69 _ 678.00 0.880 217.710 214069.45 2499447.78 0.48 __. 677.98 517.73 3.44 - 1056.08 454.25 214068.99 2499447.22 0.18 728.00 0.790 211.210 727.98 567.73 4.11 - 1056.68 453.83 _ 214068.56 2499446.63 026 i 778.00 0.700 233.4101 777.97 617.72 4.67 - 1057.15 453.41 j 214068.12 2499446.16 0.60 a - 856.00 3.080 182.990 855.93 695.68 7.09 - 1059.53 452.92 214067.57 2499443.80 3.45 ' - 1062.15 452.67 214067.26 2499441.19 - 903.00 3.340 187.650 902.85 742.60 9.70 1 0.78 953.00 4.400 189.490 952.74 792.49 13.07 - 1065.48 452.16 214066.67 2499437.86 2.13 1003.00 6.770 190.630 100230 842.25 17.93 - 1070.27 451.30 214065.69 2499433.10 4.74 1053.00 9.850 188.880 1051.97 , 891.72 25.15 - 1077.40 450.10 214064.32 2499426.01 6.18 1103.00 13.370 184.660 1100.9 940.69 35.15 - 1087.39 448.97 214062.94 2499416.05 j 7.24 1153.00 16.720; 182.1101 1149.22 , 988.97 47.96 - 1100.34 448.23 214061.89 2499403.11 6.83 _...._.._.. - 1116.11 448.05 214061.32 2499387.36 6.88 1203.00 20.060 179.470 1196.66 ' 1036.41 63.40 1253.00 22.350 177.100 1243.27 1083.02 80.93 - 1134.18. 448.61 214061.44 249936928, 4.89 1303.00 23.930 174.020 1289.25 1129.00 99.73 - 1153.76 j 450.15 1 214062.50 2499349.66 3.98 1353.00 25.2501 173.500 1334.71 1174.46 119.44 - 1174.44 r 452.41 214064.26 2499328.93 2.68 1391.00 26.220[ 173.320 1368.94 1208.69 135.05 - 1190.83 ! 454.31 1 214065.75 2499312.5_0 2.56 1482.00 26.900 174.800 1450.34 1290.09 173.67 - 1231.30 458.51 214068.96 2499271.94 1.04 1576.00 28.700 178.100 1533.49 1373.24 215.82 - 1275.04 461.19 214070.57 2499228.15 2.52 1669.00 30.420 179.930 1614.38 1454.13 260.46 - 1320.91 461.96 214070.22 2499182.28 2.09 1709.40t 31.422 180.749 1649.04 1488.79 280.76 - 1341.67 461.84 214069.59 2499161.53 2.69 1761.00 32.710 181.730 1692.77 E 1532.52 307.64 - 1369.06 461.24 214068.32 2499134.16 2.69 1854.00 35.760 187.220 1769.67 ' 1609.42 359.43 -1421.16 457.07 214062.87 2499082.18 4.66 1947.00 39.050 192.680 1843.55 1683.30 415.82 - 1476.73 44722 2140.. ` ,alr`: 7 5.02 2041.00 42.220 195.540 1914.88 1754.63 476.98 1536.06 432.25 214035.26 ' 2498967.92 j 3.91 1 2136.00 44.940 197.960 1983.70 1823.45 542.26 1598.75 413.35 214014.83 2498905.71 3.36 I 2230.00 48.140 198.320 2048.35 1888.10 610.14 - 1663.58 r 392.11 213992.01 2498841.42 1 3.42 2324.00 50.930 198.640 2109.35 1949.10 681.24 - 1731.40 369.44 213967.69 2498774.18 2.98 2418.00 53.770 199.520 2166.76 2006.51 755.15 - 1.801.73 345.11 213941.64 2498704.47 3.11 2510.00 56.370 200.290 2219.43 2059.18 829.91 - 1872.64 319.43 213914.24 2498634.21 2.91 2605.00 56.360 200.120 2272.05 j 2111.80 908.27 - 1946.87 292.11 213885.11 2498560.67 0.15 2700.00 56.360 200.340 2324.68 2164.43 986.62 - 2021.08 1 264.77 213855.96 j 2498487.15 0.19 2796.00 56.400 201.300 2377.84 2217.59 1065.70 - 2095.80 23636 213825.73 ' 2498413.14 0.83 2892.00 56.370 201.340 2430..98 , 2270.73 1144.67 - 2170.28 207.29 213794.86 ,2498.E 59.40 0.05 • • C 1 Well path Report rAt� A ctua We pat p BAKER SDI Gyro - Keeper <78- 1391' >ATK G3 MWD <1482 - 5666' >OnTrak MWD <5 HUGHES Page 3 of INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron Slot slot #A1 - Area Cook Inlet, Alaska (Offshore) Well -r--- M-17 Field McArthur River Field Wellbore M - Facility STEELHEAD Platform WELLPATH DATA (98 stations) MD Inclination Azimuth TVD TVD from Vert Sect North East Grid East Grid North DLS [ft] 1 1 [ftl Fld Vert Ref [ftl Eft] [ft] [sry ft] [sry ft] [ °/100ft] lftl 2987.00 56.390r 202.100 2483.58 2323.33 1222.73 - 2243.77 178.02 213763.79 2498266.65 0.67 , F 3081.00 56.360 202.430 2535.64 2375.39 1299.84 - 2316.21 148.37 213732.38 2498194.96 0.29 3176.00 j 54.460 202.020 2589.57 2429.32 1376.89 - 2388.60 118.79 1 213701.04 2498123.31 ; 2.03 r- 3269.00 ! 52.240 201.220 2645.08 2484.83 1450.53 - 2457.96 91.29 213671.85 2498054.65 1 2.48 3365.00 49.330 200.330 2705.77 2545.52 1524.10 - 2527.49 64.91 21364337 2497985 #7$ 3.12 I 3459.00 ] 46.560 199.830 2768.72 2608.47 1593.26 - 2593.03 40.94 213618.21 2497920.84 j 2.97 3551.00 j 43.010 199.020 2834.01 ; 2673.76 1657.57 - 2654.14 [ 19.38 213595.17 249786 F 3.91 3648.00 ' 39.950 197.150 2906.68 2746.43 1721.48 -2715.19T -0.59 213573.71 2497799.74 3.40 3742.00 37.160 196.400 2980.18 2819.93 1779.89 - 2771.28 -17.50 213555.43 2497744.09 3.01 3836.00 34.380 194.380 3056.44 2896.19 1834.74 - 2824.23 -32.11 213539.53 2497691.50 " 3.21 3925.00 31.780 193.350 3131.01 2970.76 1883.30 - 2871.38 -43.76 213526.73 2497644.65 2.99 1 4019.00 j 29.950 192.580 3211.70 3051.45 1931.51 - 2918.37 -54.59 213514.76 2497597.94 1 1.99 r 4113.00 1 29.970 192.160 3293.14 3132.89 1978.46 - 2964.23 -64.64 213503.58 2497552.35 r 0.22 4203.00 1 29.990 190.640 3371.09 3210.84 2023.42 - 3008.31 -73.53 1 213493.62 2497508.49' 0.84 4298.00 29.950 1$9.250 3453.39 3293.14 2070.83 3055.0 81.72 213484.29 2497461.97 0.73 4391.00 29.970 189300, 3533.97 3373.72 2117.21 - 3100.89 j - 89.21 213475.68 2497416.33 0.03 1 4483.00 30.0001 188.5001 3613.65 3453.40 j 2163.10 - 3146.31 -96.32 213467.46 2497371.09 0.44 4579.00 29.940 187.850' 3696.82 3536.57 1- 2210.93 - 3193.78 ' - 103.14 213459.49 2497323.80 0.34 4673.00 29.940 188.700 3778.27 3618.02 2257.72 - 3240.21 - 109.89 213451.60 2497277.56 0.45 4768.04` _ .=30.010 188.970 3860.57 3700.32 2305.09 - 3287.11 - 117.17 213443,17 2497230.85 0.16 4863.00 ` 30.000 188.790 3942.83 3782.58 2352.51 - 3334.05 - 124.51 213434.69 2497184.10 0.10 4959.00 30.000 189.270 4025.97 3865.72 2400.43 - 3381.45 - 132.04 213426.00 2497136.90 0.25 5055.00 29.910 189.250 4109.15 3948.90 2448.29 - 3428.76 - 139.75 213417.14 2497089.79 0.09 5147.00 29.780 189.040 4188.95 4028.70 2494.01 - 3473.96 - 147.02 ! 213408.76 2497044.78 0.18 5244.00 , „ 29.760 189.510 4273.15 4112.90 2542.10 - 3521.50 -15438 213399.84 2496997.45 0.24 11 5336.00 1 29.840; 190.100 4352.98 4192.73 2587.77 - 3566.55 j - 162.57 ' 213390.95 2496952.60 0.33 5432.00 29.780 190.160 4436.28 4276.03 2635.46 -3613.53 213381.41 2496905.84 0.07 -- - -- - -- - 5527.00 1 29.790 190.040 4518.73 4358.48 2682.61 - 3659.99 - 179.23 I 213372 01 I 2496859.60 ` 0.06 5624.001 29.310 189.810 4603.11 4442.86 2730.41 - 3707.11 - 187.48 213362.61 2496812.69 0.51 5666.00 ;'. -- 29.720 189370 4639.66 4479.41 2751.08 - 3727.50 - , - 191.00 213358.60 2496792.40 0.98 1 5712.00 30.050 189.820 4679.54 4519.29 2773.97 - 3750.09 - 194.89 213354.15 2496769.91 0.72 5805.00 j 29.750 189.420 4760.16 4599.91 2820.28 - 3795.80 - 202.64 1 213345.29 2496724.41 0.39 5897.00 29.420 188.980 4840.17 4679.92 2865.63 - 3840.63 -204. 209.90 213336.93 ; 2496679.76 0.43 5989.00 29.260 189.860 4920.37 4760.12 2910.65 - 3885.11 - 217.28 ' 213328.47 2496635.49 0.50 6081.00 _ 29.170 190.800 5000.67 4840.42 2955.52 - 3929.28 - 225.33 213319.34 2496591.52 0.51 1 6174.00 1 28.5501 189.950 5082.12 4921.87 3000.38 - 3973.43 - 233.41 213310.18 • 2496547.58 0.80 r 6266.00 29.710' 188.820 5162.48 5002.23 3045.10 4017.62 - 240.71 213301.811 2496503.59 1.40 6360.00 29.330 188.620 5244.28 5084.03 3091.33 4063.40 - 247.73 1 213293.67 I 2496457.99 0.42 r 6451.00 28.990 188.050 5323.74 5163.49 3135.55 4107.27 A - 254.15 ; 213286.17 249641429 0.48 6546.00 31.020 187.120 5406.01 5245.76 3182.89 - 4154.3 ,260.41 ` 78.77 249636737 2.19 6638.00 29.840 187.810 5485.33 5325.08 3229.31 4200.56 1 - - 266.46 213271.59 2496321.33 1.34 L 6729.00 29.250 187.190 5564.50 5404.25 3274.02 4245.05 r - - 272.31 213264.65 1 2496277.00 1--- 0.73 1 6820.00 30.650 186.380 5643.35 5483.10 3319.24 4290.16 - 277.67 213258.19 2496232.03 r 1.60 6912.00 31.660 185.820 5722.08 5561.83 3366.55 4337.49 - 282.72 - 213251.98 2496184.84 ' 1.14 7,010 00 - 31360, 186.430 5805.63 38 _3417.46 - 43::41 21 213245, 7 ,,2,4961 4.07 0.45 • • Chevron Actual Wellpath Report BA KER i S DI Gyro - Keeper <78- 1391' >ATK G3 MWD <1482 - 5666' >OnTrak MWD <5 H Page 4 of 5 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron 'Slot slot #A1 -9 Area Cook Inlet, Alaska (Offshore) Well M - 17 Field McArthur River Field Wellbore M - 17 Facility STEELHEAD Platform WELLPATH DATA (98 stations) MD Inclination Azimuth TVD TVD from Vert Sect North East Grid East Grid North DLS [fr1 1 1 0 1 [ft] Fld Vert Ref Eft] 1 1 [1t] [sry ft] [sry ft] [MOOR] 7103.00 30.630 186.260 5885.35 5725.10 3465.09 ! 4436.01 - 293.48 213238.82 2496086.61 0.79 7196.00 j 30.570 186.570 5965.40 5805.15 3512.17 - 4483.06 - 298.77 213232.38 2496039.71 0.18 F7290.00 29.850 186.170 6046.63 5886.38 3559.21 _ 4530.06 - 304.01 213225.99 2495992.85 0.80 1 7384.00 ` 29.240 185.230 6128.41 5968.16 3605.24 4576.18 - 308.62 213220.25 2495946.85 0.82 7476.00 a 28 940 ; 185200 6208.80 6048.55 3649.62 - 46473 - 312.68 ,213215.10 2495902.42 033 7569.00 j 28.0801 185.500 6290.52 6130.27 3693.68 -4664.92i - 316.82 213209.89 2495858.341 0.94 7608.00 1 28.030r 185.710 6324.94 6164.69 3711.89 - 4683.18 - 318.61 r 213207.65 2495840.14 0.28 L 28.030 185.710 6379.67 P 6219.42 3740.83 , - 4712.17 - 321.511 213204.04 2495811.23 0.00 j HOLE & CASING SECTIONS Ref Wellbore: M -17 Ref Wellpath: SDI Gyro - Keeper <78 -1391' >ATK G3 MWD <1482 - 5666' >OnTrak MWD<5712 - 1String/Diameter Start MD End MD Interval Start TVD End TVD Start N/S Start E/W End N/S Em - ' _ [ft] [ft] [ft] [ft] [ft] [ft] [ft] [ft] 12 - Casing 0.00 484.00 484.00 0.00 484.00 - 1052.80 455.34 -1053.88 137375in Casing 0.00 895.00 895.00 0.00 894.87 - 1052.80 455.34 - 1061.69 9.625in Casing 0.00 1430.00 1430.00 0.00; 1403.88 - 1052.80 455.34 - 1208.051 Tin Casing ,...,.. ___5700.00 5700.00 0.00 4669.15 - 1052.80 455.34 - 3744.18 , III III . Chevron Eli II Actual Wellpath Report BAKER 1%0 SDI Gyro - Keeper <78-1391'>ATK G3 MWD<1482 - 5666'>OnTrak MWD<5 HUGHES Page 5 of 5 INTEQ I REFERENCE WELLPATH IDENTIFICATION Operator Chevron ,8lot slot #A1-9 Area Cook Inlet, Alaska (Offshore) Well M-17 -] Field McArthur River Field Wellbore M-17 Facility STEELHEAD Platform , TARGETS rm Name MD TVD , North ' East Grid East Grid North Latitude 1 Longitude Shape • S [ft] [ft] [ft] [ft] [sry ft] 1 [sry ft] 1 [ -I ' ' 1483.25 - 1184.17 542.72 214154.301 2499317.00 r 60°49'53.142"N r 151°36'07.070"WIcircle M17 Tgt A (19-Sep-06) ' -1 M17 Tgt B B3(19-Sep-06) 3330.25 - 72.04 213496.10 2497549.00' 60°49'35.578"N1 151°36'19.471"W rcircle ' I 1 1 3928.25 -3303.97 1M17 Tgt C Cl (19 -117.63 21344230 2497214.00 60°49'32.268"INC 151°36'20.390W circle 1 ' ' - M17 Tgt D D3B (19 4794.25 - 3759.21 - 203.42 213345.401 2496761.00 60°49'27.785"N F 151°36'22.121"W circle , 1 5080.25 r_3890.04 -194.72 213350.901 2496630.00 60°49'26.496"N circle_i M17 Tgt E D6 (19 6162.00 4587.27 -324.57 213204.04 2495936.16 60°4919.630"N 151°3624.563W I circle 1 M17 Tgt FF - 1 1 ' 6338.461 - 4687.60 - 342.26 213183.90 2495836.29 r 60°4918.642N1 151°3624.920W circle M17 Tgt G TD 1 _ , -- - - WELLPATH COMPOSITION Ref Wellbore: M-17 Ref Wellpath: SDI Gyro - Keeper <78-1391'>ATK G3 MWD<1482 - 5666'>OnTrak MWD<5712 - 7670'> - - -1•-• Start MD 1 End MD I Positional Uncertainty Model Log Name/Comment Wellbore [ft] ' [ft] 0.00 856.00 SDI Keeper SDI Gyro - Keeper <78-856'> M-17 1 856.00 1391.00 SDI Keeper SDI Gyro - Keeper<903-1391'> M-17 1 111- 1391.00 r , 5666.00 ' AutoTrak G3 (MagCorr) ATK G3 MWD<1482 - 5710'> M-17 7--- 5666.001 7670.00 OnTrak (MagCorr) OnTrak MWD<5712 - 7670'> M-17 • • chevron Chevron - Alaska Time Log Summary Sort Well Name I Field Name API /UWI Leese/Serial _ 'CHEVNO License No./Prope. ,Ong KB Elev (R. Water Depth (ft) I M -17 !McArthur River Field 1 507332055200 l ADL017594; LB2629 2071200 79.2 185.00 I Start Date j; Our (Ars) ; Endoale_..... I Activity..... teltWCsgSz ' : Comment!: 10/14/2007 07:00 5.00 10/14/2007 12:00 Clean Mud Tank Clean and drain pits to production, complete non produced fluids and submit prior to operation. Clean welhead room under grating, Work on cleaning decks, clean suction screens on MP found part of centrifugal impellar in I suction screen of #1 pump. 10 12:00 12.00 10/15/2007 00 :00 Rig - Service Continue with deck cleaning issues, stage mud product in will head room, organize decks in preparation of working boat. Remove bails and pipe handler from TD. Start working on TDS- removed upper and lower IBOP's, could not get saver sub to break, plan to send to town and have BOT Weak in their bucking machine, need to inspect threads, Bleed 142 off of compensator, Shut in service loop, work on derrick climber, continue to drain pits, remove I : actuator from TDS label and make note of a wnent of hoses for TD, remove '' I sutra. I 10/15/2007 00:00 12.00' 10/15/2007 12:00 Rig - Service Drain TD gear box & remove rotating head seal assembly. Remove service 'loops from rig. Pull valves/seats & swabs/liners from #2 pump - looking for washout. Install new derrick climber bracket. Work boat & sort deck for next well. i I 1 10/15/200712 :00 12.00 10/16/2007 00:00 Rig - Service Coot replace head seals On TO. Inspect main shaft & upper IBOP threads. Fab lifting nag for head seals & R/U sc affofdi ng. Install rotating head 1 I 1 assembly & link adapter. Install upper 1130P. Make up#2 pump - no signs of washout or cracks after inspection. Work on charge pumps. Cont Work boat & dear 1 10/16/2007 00:00 10.00 10/16/2007 10:00 ;Rig - Service Continue work on top drive - Torque upper IBOP - Install torque arrester - 1 install link tilt - Install pipe handler - adjust alignment cylinders - - Charge iaccumulaters cylinders - drill service holes in accumulator cylinder cover plates - fill gear box w/ oil & finish installing derrick climber sheave bracket 1 10/16/200710 :00 4.00}10/18/200714:00 Skit Rig PJSbt remove storm c l a mps - remove air service line in - PTSM. Remove beaver slide - secure diverter Wires - Un-lug rig - Organize & stage equipment for rig move I 1 10/16/200714:00 2.00 10/16/2007 16:00 Rig - Service Service rig & work on rig hyd system for rig skidding system I 10/16/200716 :00 1.00 10/16200717:00 Skit Rig P.1891- Install skid guides - remove hand rails & flag off walk ways 10/16/2007 17:00 6.00 10/16/2007 23:00 Skid Rig Skid rig from leg B -1 to leg A -1 - installing jack extentions as neccesary for 1 1 1 uneven skid rails 1 10/162007 23 :00 1.00 10/17/2007 00 :00 Rig - Repair Cho/out seals OP #2 gripper 10/17/2007 00:00 0.50 10/17/2007 00:30 Rig - Repair 1 Finish chg /out gripper seals on #2 rig jack 10/17/2007 00:30 10.50 10/17200711 :00 Skid Rig Continue move rig off B-1 leg ¢er between Leg B-1 & leg A-1 & finish I removing service lines & equipment from B-1 upper leg room & instal hatches: on B-1 upper well room & continue skidding rig south U Leg A -1 10/17/200711:00 2.50! 10/17/2007 13:30 Rig - Repair Rebuild seals on rig jack gripper - re- enguage same & blew seals again - 11 Rebuild gripper & install 1/8° shim I 1 10/17200713:34 1.00 10/17200714 :30 Skid Rig Continue move do South on t/ I,eq A,1„.. I 10/17/2007 14:30 0.50 10/17/2007 15:00 ! Safety Gas alarm all hands mustered in safe breifing area & role call - False alarm Drills/Meetings 1 I 1 10/17/200715:00 100 10117200718:00 'Skid Rig !Continue move rig South on t/ leg A -1 & Tale upWl East/West skid beams 10/17/2007 18:00 2.50 10/17/2007 20:30 Skid Rig Move jacks & guide plates to skid rig East I 10/17/2007 20:30 ` 1.00110/172007 21:30 (Skid Rig Skid rig East & fine up w/ M-17 1 10/17/2007 21:30 2.50 10/18/2007 00:00 Skid Rig Had to much of gap on west side - Continue skid rig East & install other hatch I cover i 110/18/2007 00:00 1.00 10//82007 01:00 Skid Rig Finish installing hatch cover West side of rig I 1 10/18/2007 01:00 0.50 10/18/2007 01:30 Skid Rig Skid rio west & line u0 w/ M -17 10/18/2007 01:30 4.50 10/18 /2007 06:00 Skid Rig Prep top aellcr of rig - skid same & center over M-17, I 1 10/18/2007 06:00 6.00 10/18/2007 12:00 Skid Rig Install hand rails - secure rig - spot cat walk - tighten saddle clamp on south diverter line - Lug up rig - clean & origenize decks - inspect MP #1 fluid end start r /up service lines - well safe continue r/ up of rig equipment - Epoch !continue r /up of rig equipment - Quadco continued r /up of rig equipment 10/18/200712 :00 4.00 10/18200716:00 Rig Up / Rig Down continue lug up rig & function test dwk & TO - house clean - hook up service lines - walk on iron ruffne k 1 110/18/2007 16:00 ! 0.50 10/18/2007 16:30 Safety fire alarm - all hand mustered in safe breifing area & role call - false alarm 1 Drills/Meetings 1 1 10/18200716:30 ( 1.50 10/18200718 :0 0 Rig Up / Rig Down r/up bails & p/up 'fines - continue r/up service lines - woad kwadco w/ r/up 10/18/2007 18:00 3.0010/18/2007 21:00 Rig Up / Rig Down I orgenize upper well bay room - prep to p /up top section of 30" riser - p /up same & stab - m /up drill quip connection 1 2t00 3.00 10/19/2007 00:00 Rig Up / Rig Down Finish securiUng rig w/ earthquake clamps - house Clean cellar - chink dg w/ Insulation - remove extra - koorney hoses - prep for dlveder r /up - conlinue 1 deck organ & house cleaning - finish inspection of #1 MP (hest bad fluid I ends) - prep to remove & cho/out same 10/19/2007 00:00 2.00 10/19/2007 02:00 Rig Up / Rig Down I Finish securiung rig w/ earthquake clamps - house clean cellar - hook up koomey hoses to diverter valves - continue deck orgenizion & house cleaning - remove fluid block 1& 3 from #1 mp 10/192007 02 :00 2.00 10/19/2007 04:00 Rig Up / Rig Down house clean cellar- continue deck orgenizion & house cleaning -remove fluid 1 block I& 3 from #1 mp • Ar ximalator Torsion test both north & south 10/19/2007 04:00 18.00 10/19/2007 22:00 Rig Up / Rig Down ,Continue deck orgenizion & house cleaning - remove fluid block 1& 3 from #1 tap - P /up 30" mud crossw/ 20 -1/4" hydnll from stump & nip /up on riser & hook up both north & south 16" diverter lines - hook up rig deluge line - work on rig perimtor lighting - work on iron ruff neck - epoch - r /up - BHI r /up & unload I ;boat 10/19/2007 22:00 2.00 10/202007 00:00 Rig Up / Rig Down Move 16.3/4" 10k stack from east side stump to west side stump in sub base { Prep to chg/aut anul uar elmount 10/20/2007 00:00 6.0010/20/2007 06:00 Rig Up / Rig Down Conttin out 20 -1/4" annular elmont - brk & remove top - remove old 1 1 e emont bowl- remove old oil & add fresh oil - install new natural rubber dated 5 -10 -07 - continue orgenize deck & stack 5" dp - continue chg /out fluid end block on #1 mp • • Chevron Chevron - Alaska I INIII I Time Log Summary Sort , Well M -17 me 1 McAr thur River Field 507332055200 ADL017594; 017594; I LB 629 2071200 Pmpe... 79.2 (ft.. 'Water 18 5.0 (ft) 5.00 Stan Date Our (Fri) I End Date: f ` Activity _ ;eiucg Sz Comment . ,.. 10/20/2007 06:00 6.00110/20/2007 12:00 !Rig Up / Rig Down Install pitcher nipple - continue origenize deck - stack 5" dp & continue w/ chg /out of fluid end blocks on #1 Mp 10/20/2007 12:00 : 1.50 10/20/2007 13:30 Safety !Shut do operations & hold pre-spud meeting w/ all field & town support drilling Dls/Meetings 'team 10/20/2007 13:30 7.50 10/20/2007 21:00 Rig Up / Rig Down Obtain permits - House clean - Pitcher nipple to long remove same - for modifacation - continue fluid block chg /out on #1 MP - off load boat - work on I iron ruff neck - stack 5" dp 10/20/2007 21:00 3.00 10/21/2007 00 :00 Rig Up I Rig Down ..... k s - P/up stand DP & install in annular trolls - continue work on #1 MP & finish stack 5 " dp 1 110/21/2007 00:00 2.00 10/21/2007 02:00 Rig Up / Rig Down Aest function diverter from Ilnllets r ontrol station - Knnmev unit K -R valve . L 1 malfunctioning 10/21/2007 02:00 4.00 10/21/2007 06:00 Rig Up / Rig Down IRe- instal pitcher nipple - install flow line - re- tigl'akt flanges on riser 10/21/2007 06:00 12.00 10/21/2007 18:00 Rig Up / Rig Down ,Install -4" HP mud line - install beaver slide - spot last 3 sections of north 16" 1 1 ! diverter line - finish repairs on iron ruffneck - Mix mud prehydraling bentonite ' !, to mix spud mud - work on rig gylco charge pump - clean up work areas 10/21/2007 18:00 6.00 10/22/2007 00:00 Rig Up / Rig Down center up divertr stack - hook up fill & bleeder line to pitcher nipple - Arles swaco work on koomey unit - & function test same - continue worker koomey ' - unload boat strap 13 -3/8' csg - Orr DB tongs & r/up DD tongs - work on rig acceptance chic list 1 10/22/2007 00:00 6.00 10/22/2007 06:00 Mix Mud Mix mud, WOrk with Swaco on Koomev controls, CLean out and raise mud !trough, install sideboards, Roll up umbilical cord, Build walkways to BHI, 1 1 EPOCH and Baroid shacks. Bolt up diverters and secure same. 10/22!2007 06:00 6.00 10/22/2007 12:00 Preparations Drain cuttings dump line, Remove 90 and install 12 x 10" Vic reducer, MU cuttings hose in cellar and drop in upper welbay, Continue to mix mud and working on fivo ler system controls. Prep to install Lower [BOP and saver sub 10/22/2007 12:00 9.00110/22/2007 21:00 Preparations Work on housekeeping, Attempt to install lower IBOP pipe handler not working correctly, trouble shoot same, found hydraulic hoses not hooked up 1 ' I (correctly and spacers not in correctly. Set compensator, and alignment, 1 1 Organize decks, Assist MWD, work on degasser pump, continue to mix mud and troubleshooting diverter system. 1 10/22/2007 21:00 3.00 :10/23/2007 00:00 SOP Test - Surface Function test dive system, works on manual procedures, closed on 3 4/2° DP, unload rig floor, RU to flood diverter, add weight to rig tong counter weights 10/23/2007 00:00 11.00 10/23/2007 11:00 Rig Up / Rig Down R/U hose to Annulus Drain. Flood stack w/ fluid. Tighten diverter leaks. : Repair 4° Demob in Cmt. Room. Test lines to 2700 #. Dress Shakers wit 84 !mesh shaker screens. Clean out desilter. Mix mud. Remove 3 -1/2° handling ! 1 i eqpt. from rig floor. 10/23/200711:00 3.50 10/23/2007 14:30 Drill Pipe - Pick -Up ! RU 5° handling egpt on rig floor. P/U 5" DP and stand in derrick. 1 I Lay Down 10/23/2007 14:30 3.50 10/23/2007 18:00 BOP Test - Surface Test Diverter, Accumulator. PVT and gas alaarms with AOGCC, Ball valves , open time = 19 sec & Annlar closing time - 45 secs. 10/23/200718 :00 0.50 10/23!200718:30 Trouble Shoot Test Deluge System. Tested OK. Problem , 10/23/2007 18:30 5.50 10/24/2007 00:00 Drill Pipe - Pick -Up / ' GIH P/U 5" DP. Tagged mud line at 463.7'. Lay Down 10/24/2007 00 :00 i 7.50110/24/2001 07:30 DrR lie - Pick -Up / Finish p/up - rabbit & strap 5°19.5# 5-135 dp total 66 std in derrick = 6223.87 10/24/2007 07:30 2.50 10/24/2007 10:00 Drill Pipe -- Pick -Up / P /up rabbit & strap 20 jts HWDP + combo jars 1 1 Lay Down 1 10:00 0.50 10/24/2007 10:30 Rig Up / Rig Down Walk lint w/ crew on r/up of 6" over boerd lines from annulus - pit over board dump line - water & steam hook up to rain for rent tank I 1 110/24/2007 10:30 1.00110/24/2007 11:30 Safety I Trainning on diverter operation & use w/ day crew - diverter drill & abondon Drills/Meetings platform drill w/ all platform personnel 10!24/200711:30 4.00 10/24/2007 15:30 Rig Up ! Rig Down Continue r/up of 6" over board lines iron annulus valves - rlup of steam & potable H2O to rain for rent tank 10/24/2007 15:30 2.50 10/24/2007 18:00 Safety Trainning on diverter operation & use w/ Night crew - diverter drill & abondon 11 Drills/Meetings I platform drill w/ all platform personnel 10/24/2007 18:10/24/2007 16:00 3.00 10/24/2007 21:00 Rig Up / Rig Down Finish r /up of 6'" overboard lines from aftaulus valves - potable H2O & steam 1 to rahn for rent tank flit same w! 400 bbd of potable H208, heat same wi steam - R/ up WOTC tog tongs. Clean well bay. 10/24/2007 21:00 1.50 10/24/2007 22:30 Rig Up / Rig Down Calibrate block height with Totco 10/24/2007 22:30 1.50 10/25/2007 00:00 Casing/Liner - P/U double pin pup jt. and make up csg. hanger. Running I 1 110/25/2007 00:00 8.00 10/25/2007 08:00 Casing/Liner - I M/U Hanger to bottom pup jt. L/D same. M/U Hanger running tool and 2 jts. Running 113-3/8" csg. GIH to drift annular and riser. Set down in wellhead. 1 inch short of landing out. POOH. Sheared set bolt on compression sleeve. 1 110/25/2007 08 :00 4.00 10/25/200712.00 Casing/Lifter - Drill out bolt to remove compression ring, Remove rings and seals. GIH and Running set hanger. Landed In right spot. PU pipe and tap hole. Install rings end seals. Rerun hanger. Still setting down 1 high and sheared bolts again 10/25/2007 12:00 5.00 10/25/2007 17:00 Rig Up / Rig Down 1 Change out mud line in shaker area. Clean up degasser room. Mix spud /mud. Unload boat. Work on cmt. line. 1 10/25/2007 17:00 1.00 10/25/200718:00 'Rig - Service Service top drive. instal stabbing board winch. 10/25/2007 18:00 3.50 10/25/2007 21:30 '1 Casing /Liner - Pull up casing hanger. Install master bushings and slip bowl. Break off 1 1 Running running tool. Install ring onto top of hanger. Make up running tool. Weld ring I on to running tool. Finish rigging up cmt. line. 1 ' !10/25/2007 21:30 2.50 10/26/2007 00:00 Casing/Liner - Remove slip bowl and master bushings. G1H w/ hanger and set same in Running wellhead, Landed out comedic/. Run in two hold down pins. POOH and checked landing of hanger. OK. Prepare to laydown casing and hanger. 1 10/26/2007 00:00 1.50110/26/2007 01:30 Casing/Liner - L/D 13 -3/8" running tool, hanger, and 13 -3/8" csg. L/D handling equpt. Running 10/26/2007 01:30 3.50110/26/2007 05:00 !Rig Up / Rig Down I R/U stabbing board. Change oil n top drive: 0 • Chevron Chevron - Alaska I 11 10 0 Time Log Summary Sort M-17 Well McArthur River Field 507332055200 IAA 0 ! LB 629 207120 , 79.2 (ft.: wai (ft) 185.00 'runt ' I .Dor ( e)) End Date f Assa ewce s ] _ ..�_ - Comment `. _ A 10/26/2007 05:00 1 2.00110/26/2007 07:00 [BHA - PU /LD R/U handling equpt. Load rig floor with bit, stabs, and x- overs. 10/26/2007 07 :00 6.50110/26/2007 13:30 ]BHA - PU/LD I M/U BHA. Install and test MWD: , 1 10/26/2007 13:30 2.00 10/26/2007 15:30 : Safety 'Held Fire and Abandon Drills with new crew. Held and walk through diverter 1 Drills/Meetings !drill. 10/26/2007 15:30 C 5.00110/26(2007 20 :30 Tripping In GtH to 462'. Circulate out water from the drive pipe. Displace water with 9.2#/gal. Fresh water mud. Wash from 462' to 465'. 10/26/2007 20:30 2.00 10/26/2007 22:30 Directional - Gyro Survey with Gyro tool while POOH to wellhead. Could not get Gyro survey. Survey Check out Gyro Tool and block height counter. 10/26/2007 22:30 ] 1.50 10127/2007' 00:00 Trip Out of Hole (POOH to change out Gyro Survey Toot. 1 1 ,10/27/2007 00:00 2.00 10/27/2007 02:00 BHA - PU /LD Load Gyro Tool. M/U BHA. Calibrate block height. 10/27/2007 02:00 3.00 10/27/2007 05:00 Directional - Gyro I Run Gy ro survey at 50' intervals from 169' to 419'. Clean out drive pipe from I I I Survey . ebb' to 465'. Survey at 469'. 10/27/2007 05:00 10.00'10/27/2007 ,15:00 Drilling - Rotate ..-iii. Drill from 480' to 823'. Max gas encountered 202 units (CZ1 coal). No mud R cu Avg. Pen. Rate 34.3'/hr. Max. pen. rate was 120' /hr. no major losses to 1 , ` .. ' C; ,hole but h ad 210 bbl seeps a loss through out hole section ran LCM { concentration @ 2.5 ppb @ start & mix 2.b ppb on the fly '10/27/2007 1 5:00 1.50110/27/200716 :30 1DrIl ing- Slide (Slide from 823' to 903'. Take directional surveys. 1 1 ' 110/27/2007 16:30 1 1.50110/27/2007 18:00 ;Circulate & Condition 1 Circulate and condition hole at 903'. Pump 40 bbls. nut plug sweep. Pumped 11 at 15 bbls. /min. rate. Pill came back at 2775 strokes pumped. Calculated strokes with gauge hole 4415 strokes. Pill back 1690 strokes early. Mud wt. 1 in and out 9.3# /gal. 1 10/27/2007 18:00 C 3.00 10/2712007 21 :00 Trip Out of Hole Check well for flow. No flow. POOH pumping out of hole. No problems. Pumping 10/27/2007 21:00 0.50 10/27/2007 21:30 BHA - Handle IDownload MWD. 10/27/2007 21:30 2.50 10128/2007 00:00 ]BHA - Handle UD stabs. Rack back BHA. Break out bit. 1 1 1, 1110/28/2007 00:00 0.50 10/28/2007 00:30 I BHA - PU /LD Change out stabilizer on mud motor to 12 -1/4 ". UD motor. ' 10/28/2007 00:30 4.00110/28/2007 04:30 'BHA - PU/LD f M/U Jetting Tool. Change heads on tongs. M/D 17 -1/2' bit and x- avers. 1 1 110/28/2007 04:30 1.50 10/28/2007 06:00 ! Tripping In GIH w/ washing tool to 430'. Valve on suction of mud pump left partially !opened and drained 3 bbls. to pump room floor. Clean up floor in pump room. 10/28/2007 06:00 2.00 10/28/2007 08 :00 Wash Wash with jet washing tool from 430' to 480'. wash with 20 rpm and 150 spin @ 700 #. Mace 3 slow passes through the ama. Wash out of hole to wellhead. Wash welhead. 1 1110/28/2007 08:00 2.00 10/28/2007 10:00 I BHA - PU /LD UD washing assbly. Clean clay ball off of bit. 10/28/2007 10:00 2.00 10/28/2007 12:00 Casing - Rig Up / Rig l R/O Spider. M/U X-over drive sub for safety valve. Change elevators. Down Running Change tong heeds on tongs. R/U casing M up line. P/U shoe jt• 1 ! Equipment 10/28/2007 12:00 9.00 10/28/2007 21:00 Casing /Liner - Run 13 -3/8" 68# L -80 Goo. w/ cent. and ecn stage took 893', 79& 9 ECP at Running 453'. Set hanger. Check out landing position. P/U hanger 3' above wellhead.' 1 10/28/2007 21:00 3.00 10/29/ 2007 00:00 Circulate & Condition Circulate and condition hole to circulate, Break cafe. slow and bring pumps to 5.5 bblaimla. rate. arc. bottoms up. Hole clean. No gas on bottoms up. Pumped 75 bbls. mud push. 1 10/29/2007 00:00 0.50 10/29/2007 00:30 Cement - Primary Pump 75 bbls. Mud Push into casing. 1 7 - Test Land Hen get Run Remove in sub. Install cement 10/29/2007 00:30 2.50 10/29(2007 03'00 Wellhead est ger hanger pump head. MU tinesto cement manifold. Have PJSM with crews. Lost approximately 139 bbts. card. mix water. 1 10/29/2007 03:00 21.00 10/30/2007 00:00 Preparations Remove cement head. Install circ. swedge. Hook up mud lines. Back out hanger hold down pins. Pull hanger from wellhead. Monitor well while waiting!. on cement additive for mix water. Fill pit #7 with 85 bbls. water and heat 'same to 85 degrees. Add 100 bb's. water to rain for rent tank and heat to 85 11 degrees. Change out 2 manifold valves on mud manifold for overboard line. ! Clean under rig floor and BOP area. R/U Schlum. blender. Put 68 bbls. mix i water in blender and add cement additives to water. I 10/30/2007 00:00 1.50110/30/2007 01 :30 Circul ate & Condition 1171/2 Break circulation with 19 bbls., shut down and land hanger, run lock downs j 1 .10/30/2007 01:30 1.00',10/30/2007 02:30 Cement - Rig Up / 171/2 PJSM - R/D circulating head and R/U cement head, pressure test cement Rig Down Equipment ! 1Iines to 3000 psi. 10/30/2007 02:30 2.50 10/30/2007 05;00 Cement - Primary 171/2 Mb( and pump 147 bb's. Class G 650 sxs cement @f15.8 trigs mixed with das Bfok; drop plug and displaced wen931 bbls. of 9.4 lb/gat mud, did not bump plug and pumped 3 bbls. past, 1/2 of shoe track. Check float with 1/2 Mk flow back OK. Drop bomb and pressure up to 200 psi. with 0.5 bb's. ,,. Loaded top plug and last. i 10/30/2007 05:00 1.00110/30/2007 06:00 Circulate & Condition 171/2 Displace cement with rig pumps, got preflush back @ 88 bb's. away and 'pumped total of 317 bbls. 10/30/2007 06:00 : 4.00 10/30/2007 10:00 Cement - Waiting 171/2 Blow down tines, heat up 300:bbts, FIW in rain for rent tank, drain trip and degasses tanks back to active pits. I 1 10/30/2007 10:00 4.001,10/30/2007 14:00 Cement - Waiting 1 17 1/2 ,Broke circulation to confirm two 6" annulus open with 8 bbls. Mix-up 37 bbl. ' 'mud push and 130 bbls. of CACL volumes for second stage on cement job. 1 Dump desander pit and clean shakers. Assist Schlumberger and held PJSM. ; 10/30/200714:00 0.50 10/30/2007 14:30 Circulate & Condla PJSM M with Schlumberger, pump 33 bbts, mud push with rig pumps @ 4 1 1 bpm W/ 110 psi, switch to Schlumberger. 10/30/2007 14:30 3.50 10/30/2007 18:00 Cement - Primary 17 1/2 Schlumberger pumped 76 bb's. G cement, followed by 188 bbls. G cement 1 I mixed with CACL / FIW had trouble and pumping cement rates vanea If/ 1 bpm @ 114 psi. t/ 5.1 bpm @ 450 psi. finished pumping with 48.3 bbls. @ 115.6 lb /gal of cement mixed with gas block 3.4 bpm @ 310 psi. Schlumberger I displaced with 70 bbls of mud @ 6 bpm with 514 psi. slowed rate down to 3 1 1 bpm @ 279 psi. plug bump and pressure up to 1587 psi and held for 10 mins. I 1 1 1 1 Total cement pumped 312.3 bbls. and got 62.3 bbls. back to surface. Monitor !, annulus for gas 0 %. 1 1 10/30/2007 18:00 5.00110/30/2007 23:00 Cement - Rig Up / 117 1 /2 Blow down cement lines from rig floor and clean -up cement equipment, R/D 1 Rig Down Equipment 1 two 6' lines from annulus wash and blow down, remove one valve and blind flange, reduce other to 2" and gauge. Back out landing joint and L/D same with Vetco Gray hand. 1 1 1 10/30/2007 23:00 1.00110/31/200700:00 BOP - Nipple Down 117 1/2 Nipple down diverter system. • • Chevron WI Chevron - Alaska Time Log Summary Sort Well Name :Field Name ,API /UWI 1Lease/Serial ICHEVNO License No./Prope... Orig KB Elev (ft... I Water Depth (ft) M -17 McArthur River Field 507332055200 1 ADL017594; I LB2629 2071200 79.2 185.00 Start Dee our firs) End Oats � - [ Activity BWDag Sz -- - `k.omment 10/31/2007 00:00 6.00 10/31/2007 06:00 BOP - Nipple Down 1 Nipple -down bell nipple, remove turn buckles, unbolt diverter ball valves slide ] 1 back and hang -off, unbolt flow cross. 1 10/31/2007 06:00 3.50110/31/2007 09 :30 'BOP Nipple Down 17 1/2 Remove bell nipple from sub -base and set hydril and flow cross on drillefs i side stump and secure same. Remove second 6" annulus valve and reduce to I 2" valve install gauge. 10/31/2007 09:30 5.50 10/31/2007 15:00 BOP - Nipple Down 17 1/2 Nipple down 1 riser section, pump out before removal and UD in upper well head room. R/U air hoist in upper well room. I 10/31/200715:00 4.00 10/31/2007 19:00 BOP - Nipple Down 1171/2 IPJSd M with CVX production on work in well room - welder cut out grating to remove adapter head which was welded in at installation. R/U air hoist in upper well room. Production shut in welts and remove all gauges. PJSM. 11 10/31/2007 19:00 2.00 10/31/2007 21:00 BOP - Nipple Down 1 117 1/2 Remove second section of diverter and adapter spool from 30" casing head ill and prep 13 3/8" casing for Vetco Gray 5,000 psi MSP MB -220 Multi -bowl I wellhead. 1 10/31/2007 21:00 3.00111/1/2007 00:00 BOP Nipple Up 17 1/2 Remove flanges and lower 13 5/8" X 5K psi MB-220 Multibowl well head on to I 13 3/8" casing, inject plastic into same and test 13 3/8" dig by web head connection to 1800 pal for 30 minute, test goo3: 11/1/2007 00:00 6.00111/1/2007 06:00 BOP - Nipple Up 17 1/2 Pick -up DSA and two 16 3/4" riser section on well and make -up bolts and clamps with sweeney. Change two suction valves on hydraulic air pumps of 1 1 accumulator to ball, also valves on air supply. Record RKB -,Pren for 16 3/9; 1 LOOP stack. Quadco worked on PVT system and installed monitor in pits and I trouble entire system. 1 11/1/2007 06 :00 1 6.00 11/1/200712 BOP - Nipple Up 171/2 PJSM set BOP stack and re- tighten all bolts, Remove outside kill valve lobe 1 installed on choke manifold, break out valves #10 and #11 on choke manifold to be change out. Remove sleeve insert from bell nipple, finished up accum. I Quadco worked on system trouble shoot system and data link with EPOCH. Calibrated block height and weight indicator. I ! '11/1/2007 12:00 6.00 11/1/2007 18:00 BOP - Nipple Up 17 1/2 'Install two valves on choke manifold, install 3 1/8" HCR valve on kill line of :mud cross, rebuild High /Low By -pass valve on accum manifold. 1 11/1/200718:00 6.00 11/2/2007 00:00 BOP - Nipple Up 171/2 Finished install on valve #10 & #11 of choke manifold. kill line hose and' 1 1 turn target tee on choke valves and install hose on same. Slide short sleeve into bell nipple and set on hydra, RN turn buddes. Hook -up accumulator � hoses to stack change out two damaged section. Horkeeping. turn-buckles and aline stack/bell ni le bolt bell nipple to flow pan 11/2/2007 00:00 7.00111/2/200707:00 BOP Nipple 121/4 Tighten pP Pa PP Up nipple, and connect flow line. Pressure up on accum and High /low By -pass valve on 1 manifold leaking, replace. Pressure up system and function test equipment, 'make-up test jts. 11/2/2007 07 :00 2.50 11/2/2007 09:30 :BOP Test - Surface 121/4 FN-up stack and choke manifold. Shell test 25014000 esi o n nuns Hydrostatic teak on bell nipple tighten bolls, check for teaks on equipment. - OK. I 11/2/2007 09:30 2.50 11/2/2007 12:00 BOP Test - Surface 12 1/4 ,Start to test BOP and bell nipple leaked - P/U and re -seal groove, also work on air boot. Pressure up and bleed off hydril several times. 11/2/2007 12:00 6.00 11/2/2007 18:00 BOP Test - Surface 12 Test BOP - witness by AOGCC loo Grimaldi - test 250/4000 psi 5" rams, Mud 1 cross manual valves and kill/choke HCR, coke manifold (Flow check manual & hydraulic chokes), top -drive and floor valves. Ptefwrn accumulator by operating from southwest remote console by trucker. Test good. 11 11/2/2007 18:00 1.50111/2/2007 19:30 BOP Test - Surface 12 1/4 Change out test joints for 5" dp to 9 5/8" csg. - space out to test bottom rams { 1 and Hydril. I 1 11/2/200719:30 I 1.00 11/2/2007 20 :30 .1801 Test - Surface 12114 Test hydro and bottom rams to 250/2000 psi with 95/8" csg. 11/2/2007 20:30 1.00 11/2/2007 21:30 1 Wellhead - Install or 12 1/4 [Pull test plug and install wear bushing, top @ 70.8'. I Retrieve Wear Bushing 1 11/2/2007 21 :30 1.50 11/2/2007 23 :00 Rig Up / Rig Down { 121/4 UD 95/8" test joist, blow down equipment and lases. ` I 1 11/2/2007 23:00 1.00 11/3/2007 00:00 BHA - PU /LD 12 1/4 Load tools on rig floor to be P/U on BHA, prep for same operation. 111/3/2007 00 :00 0.75 11/3/2007 00 :45 Rig - Repair 121/4 Switch accummulat or hoses on kill & choke to make controls conrieCt at 1 panels function test same - good, also tighten leaky connection on dry -lock 1 of Hydril hose. 11/3/2007 00:45 6.25 11/3/2007 07:00 BHA - PU /LD 12 1/4 Pick -up 12 1/4" BHA with Baker /Inteq - test MWD - RIH to ECP @ 454' - Up wt.102K, Dn wt.105K 11/3/2007 07:00 2.0011/3/2007 09 :00 DrillIng - Rotate 121/4 DAt ECP /Slane Collar f/454' - 11461' - bit wt.10 -12K, 50 RPM w/ 5-12K torque, pumping 10 gamin w/ 700 psi. Up wt.105, Dn Wt. Rot wt. t 1 11/3/2007 09:00 1.00111/3/2007 10:00 Rig - Repair 12 1/4 Mud ditch in cellar leaked - fixed to contained fluid back to the active. 1 11/3/2007 10:00 0.50 11/3/200710 :30 Drilling - Rotate 121/4 Continue drilling out ECP /Stage Col sir 6461' - t/ 468' - bit wt. 10 -12K, 50 RPM w/ 5-10K torque, pumping @ 11 bpm w/ 700 psi. Up wt.105, Dn wt. 100K, Rot wt. 102K 1 11/3/2007 10:30 2.50 11/3/2007 13:00 Wash 12 1/4 Wash f/ 468' - V 836' a few cement stringers, tag solid- circulate 15 minutes. 11/3/200713:00 1.00 11/3/200714:00 Casing - Testing 1121/4 Test 13.3/8' casing to 1500 psi for 30 minutes. 11/3/2007 14:00 4.50 11/3/2007 18:30 I Drilling - Rotate 12 1/4 1 Drill out cement and float/shoe f/ 836' -V 89b' - dnll our cement V 903' and 1 drilled 20' new hole f/ 903' - U 923'. 1 11/3/200718:30 1.00111/3/200719:30 I Circulate & Condition 1121/4 Circulate and condition mud to 9.3 weight in and out_ Held PJSM for FIT test. 11/3/200719:30 2.50 11/3/2007 22:00 Formation Integrity 12 1/4 R/U equipment and circulate thru same - perform FIT test to 12.8 Ib /oal EMW. Test R/D and blow down choke manifold. I 11/3/2007 22:00 1.50 11/3/2007 23:30 Drilling - Rotate 121/4 Rotary drill f1932' - I/ 949' - bit wt. 7 -10K - 60 RPM @ 8k torque, 11 born ff 725 psi. Had trouble with Gyro Survey tool and lowered pulsion dampener to 600 1381. 11/3/2007 23:30 0.50111/4/2007 00:00 Drilling - Rotary (With 12 1/4 1 Slide f/ 949' - V 974', Bit wt. 10 -20K, 10.6 bpm @ 850 psi, Up wt. 121K, Dn I Motor) wt.118k, 1 11/4/2007 00:00 1.50 2007 01 :30 Drilling - Rotary (With 121/4 Drilling f/ 974' - V 1046', sliding and survey with gyro on kick -off section well. - Motor) Up wt. -120K , On Wt. - 118, bitwt.l0 -20K, 10.6 bpm @ 850 psi. 11/4/2007 01:30 0.50111/4/2007 02:00 Circulate & Condition 12 1/4 Circulate well Scientific having trouble with gyro receiving signal. 11/4/2007 02:00 6.00 11/4/2007 08:00 Drilling - Rotary (With 121/4 Drill f/ 1046' -1/ 1420'; slIde and rotate section for kick-off, WOB 10-15K. Motor) 112.5 bpm @ 1050 psi. Up wt, 125K, Dn wt. 125K, when rotating 122K �@ 55 11 1 RPM w/ 3 -5K torque. 0 • Chevron Chevron - Alaska Time Log Summary Sort ep Well Name -_- Field Name - -- API /UW1 ' Lease/Serial '.CHEVNO -_- License No./Prope ',Orig KB Elev (f .Water Depth (fl) - M -17 McArthur River Field 1507332055200 IADL017594; LB2629 12071200 79.2 185.00 _suertDate 1 Dur(hrs) F End Dane i Activity 1:aitlCeg. Sz1 - - : Comment' 11/4/2007 08:00 1.00 11/4/2007 09:00 Circulate & Condition 12 1/4 Circulate bottoms for geologist formation sample - reciprocate drill strings. 11/4/2007 09:00 0.50111/4/2007 09 :30 Drilling - Rotary (With 1 121/4 Rotary Drill 8 1420' 41 1435' • 55 RPM @ 2.4 K torque; 12.5 bum @ 1050 psi. 1 Motor) Up wt. 125, On wt. 125, Rot wt. 11/4/2007 09:30 [ 1.50 Circulate & Condition 12 1/4 1Circulate & condition mud - geologist checked formation sample - 30 bbl high -vis walnut sweep followed by LCM pill, walnut sweep back early @ 1450 stks- continue circulating hole clean. 11/4/200711:00 1.50 11/4/200712:30 [Trip Out of Hole 1 12 1/4 Monitor well for 10 muss: POOH pumping (/1435' - t/ 894. l 11/4/2007 12:30 0.50 11/4/2007 13:00 Circulate & Condition 112 1/4 Check for flow - OK, circulate bottoms -up @ shoe. 11/4/200713:00 1.50 11/4/200714:30 'Trip Out of Hole 112 1/4 POOH from shoe - stand back, Jars and HWDP in derrick. 11/4/2007 14:30 5.50111/4/2007 20:00 BHA - PU /LD 12 1/4 PJSM with Baker - L/D 8" BHA - recover data from tools, all good. 11/4/200720:00 1.00111/4/2007 21:00 Wellhead - Install or 1 121/4 Had to wash wear bushing area to retrieve. Install hose on possum belly of Retrieve Wear 1 shakers to over board cement. Clear floor of equipment. 1 Bushing 1 1 11/4/2007 21:00 2.00 23:00 Casing - Rig Up / Rig 1 12 1 /4_�R/U Weatherford 9 5/8" csg equipment and held PJSM for same. I Down Running 1 1 Equipment 11/4/2007 23 :00 1.00 11/5/2007 00:00 Casing/Liner - 121/4 I P/U 95/8" csg. shoe track - also transferred 110 bbls. total H2O for active pits Running for mud push, 1 11/5/2007 00:00 3.50,11/5/2007 03:30 Casing /Liner - 12 1/4 ,Run 9 5/8" L -80 40# Casino & 9 5/8" Davis Lynch Fxtemal Casing oack @L& Running state collar to 872' Drifted casing with 8.679 Rabbit. 1 11/5/2007 03:30 0.50 [ Condition 04 :00 Circulate & Cdition 1 121/4 Rig up cement hose, and circulate bottoms up © the 13 3/8" casing shoe. 1 11/5/2007 04:00 2.00 ,11/5/2007 06:00 Casing /Liner - 12 1/4 : Continue Running 9 5/8" 40# L -80 Casing. Pick up 20' pup dressed with Vetco! 1 .. Running Gray 13 5/8" x 9 5/8" Fluted Hanger. Make up landing joints . RIH hole & "yLand Hanger with Casing shoe Cad 1430.91' MD. Rig up circulating Swedge. 1 1 11/5/2007 06 :00 4.00 11/5/2007 10:00 Circulate & Condition 12114 Circulate & reciprocate casino with pump rates from 5.8 bbls per stn. Up WT I 120 IOp, Down WT 10510p. pump pressure 110 - 125 psi. Schlumberger X makeup Mac water & liquid adds. 1 1 11/5/2007 10:00 0.50 11/5/2007 10:30 Safety 12 1/4 ,Held pre job safety meeting on cementing. Make up cement Head & Break Drills/Meetings icirculation with Schlumberger & test line to 4000 psi. ( Good Test) 11/5/2007 10:30 1.00111/5/200711 :30 Cement - Primary 121/4 Batch up 57 bills 15.8 G Cement GAS BLOCK Scurry, while circulating with rig pump. Shoe depth c 1430' with ECP 850' ail at MD 11/5/2007 11:30 1.00 11/5/2007 12:30 Cement - Primary 12 1/4 Pump Stage 1 Cement job. Pump 50 bbls of 10 ppg Mudpush II with Rig Pumps. Pump 57 BBLS 15.8 ppg G GasBlock Slurry. Drop Davis Lynch 1 1 Wiper Plug. Using Cement Unit Displace & Bump Plug with 102.75 bbls of 9.3 11 I Mud. Bump plug and pressure up to 1000 psi psi over final displacement !1 pressure). Bleed off pressure, check floats OK. Cement volume was 50% excess of open hole (see cement report for liquid adds). Full returns throughout job. 1 11/5/200712:30 1.00 11/5/2007 1 3:30 Cement - Primary 1121/4 Drop Davis Lynch Opening Bomb & Load head with closing plug. Waft 5 mkt & pressure up to 400 psi with 0.7 bbls & inflate ECP, Stage up to 600 psi total ' pumped 1.67 bbl/ stage pump up 670 psi and shift stage collar. Circulate 1 bottoms up with rig fop• tie mud mush and a trace • . Sc lumberger prep batch s cement . 1 11/5/2007 13:30 1.00 11/5/2007 14:30 1 Cement - Primary 112 1/4 Pump Stage 2 Cement Job. Pump 50 bbls of MudPush II with Rig Pump. ! 1 1 Pump 32 bbls of 15.8 ppg G GasBLOCK Slurry. Drop closing Plug. Opened 1 up cement head to verify plug has left head. Use cement unit to displace & 1 ;bump plug closing stage collar with 66 bbls of 9.3 ppg. Pressured LID to 1,9ftfl. 1 1 psi (1200 psi above final displacement pressure). Full retums and cement to 1 surface. Bleed pressure to 0 got back 2.25 bbls. Cement in place @ 14:20 1 1 Hrs. ( see cement report for liquid adds.) 1 , 1 111/5/2007 0 7 14 :30 3.00 11/5/2007 17:30 Wellhead - Test 121/4 Drain & Wash out stack. Lay down cement tread & 95/8" landing joints. Wash' out well head & set 95/8" Pack off. Test same to 5000 psi ( Good test) Lay down running tool. 11/5/2007 17:30 3.50 11/5/2007 21:00 I BOP - Nipple Up 12 1/4 1Change rams in single gate from 9 5/8" TO 5 ". 1 11/5/2007 21:00 ( 2. 00111 /5/2007 23:00 BOP Test - Surface [12 1/4 'Test 5" pate rams in single gate to 250/4000 psi good test. Mat test plug. 11/5/2007 23:00 1.00 ,11/6/2007 00:00 Wellhead - Install or 12 1/4 ' wear bushing & lay down test joint. 1 Retrieve Wear Bushing ! 111/6/2007 00:00 1.50 11 /6/2007 01 :30 MIxMud 95/8 Service rig . Start working on cleaning tanks & Mixing 9.1 ppg 2% KCL W/ Clay s Gem Mud system. 1 1 01:30 4.00 11/6/2007 05:30 BHA - PU /LD 19 5/8 !Make up 8 1/2" BHA. Used Mill tooth Bit + Bit Sub + 8 3/8" Sting stab + 61/4" 1 1 ' 1 Drill collar + Sting Stab + 8 - 6 1/4" Drill Collars + xo + 5 joints 5" HWDP + 1 1 1 Daily Bumber Sub Jar combo. + 19 - 5" HWDP. RIH tag up @ 849' Up wt 11 110 kip Down Wi' 105 kIP. 11 11/6/2007 05:30 2.50 11/612007 08 :00 Dril g - Rotate '95/8 Oral Stage comer & ECP Plugs f/ 849' - To/ 869' W/ 500 gpm, 10-15 kip on bit 1 1 & 70-80 RPM. 11/6/2007 08:00 0.50 11/6/2007 08:30 'Tripping In 1 9 5/8 RIH & Tag up @ 1325' (18' above float collar). 1 11/6/2007 08 :30 I 0.50 [ 11/6/2007 09:00 'Circulate & Condition 195/8 Circulate Bottoms up r 9 bbl per min 500 psi. 1 1 11/6/2007 09:00 1 1.00 11/6/2007 10:00 Casing - Testing 19 5/8 Test casing on chart to 2500 psi for 30 mins OK. Bleed off pressure & prep for. 1 choke drill. 11/6/2007 10:00 1.00 11/6/200711 :00 Safety 95/8 Conducted choke drill with rig crew. Found that valve on U -Tube of gas buster Drills/Meetings was [dosed, causing Gas buster to fill and flow from relief valve on top of buster. Wind blew mud across the drill. Most of the water based drilling mud was contained on the drill deck. About 5 gallon reached the water. See Sight Safe report for details. 11/6/2007 11:00 2.50111/6/2007 13:30 Drilling - Rotate 1 9 5/8 ,Drill stage tool junk, plugs, and cement to top of Float Collar @ 1343'. Drill Float collar & shoe track & 20' of new hole to 1455'. Cement in shoe track drilled @ 150' -200' per hr. With 120 rpm 15 kip on bit & 500 GPM. Circulate 1 Bottoms up. Had Mostly Clay & Some Coal. We did cut a 4' coal seam. 1 11/6/2007 I 0.75 11/6/2007 14:15 Formation Integrity 19 5/8 Conduct FIT. Pressure up to 260 psi with 9.3 ppg Mud for a 12.8 ppg Mud wt Test 1 Equlvatent. 1 11/6/2007 14:15 1 3.75111/6/2007 18:00 Trip Out of Hole 1 9 5/8 'POOH. P/U = 118k, hole taking correct fill. • III Chevron , Chevron - Alaska Time Log Summary Sort Well Name Field Name IAPI /UWI Lease/Senal iCHEVNO License No. /Prope. Ong KB Elev (ft ...' Depth (ft) M -17 I McArthur River Field 507332055200 ADL017594: I LB2629 2071200 79.2 1 185.00 ._._ sten. Our (hrs). 1 Date- 1. - ActlYlly I BfICsgSz1 Comment 1 11/6/2007 18:00 6.00 11/7/2007 00:00 4- Preparations 9 5/8 R/U flow diverter for Autotrak system on mud manifold. Program /test tools on , I deck. Install sensator on standpipe. Install auto digger on driller's console. Cleaning pits & mixing mud. Move subs/bit to walk. 11/7/2007 00:00 3.00 11/7/2007 03:00 'Preparations 95/8 Cont mixing mud & building volume. Finish testing tools & move same to catwalk. P/l1 subs & XO. Clean shaker pits for displacement 11 1 11/7/2007 03:00 4.50 11/7/2007 07:30 BHA - PU /LD 95/8 Begin P/U Autotrak & Litho tools. Test programming &communication 1 I between tools - good. P/U flex pipe & RIH. 1 11/7/2007 07:30 1.0011117/2007 08:30 'Tripping In 9 5/8 ITIH w/ BHA #5 & HWDP U shoe @ 1435'. I 11/7/2007 08:30 1.50 11/7/2007 10:00 'Circulate & Condition 9 5/8 Circ hole & displace w/ 9.1 ppg KCI mud. Rig up test pump & test kelly hose and BHI connections on stand pipe goose neck to 3500 PSI 11/7/2007 10:00 1.50 11/7/200711:30 1BHA Inspect/Test Iect/Test 195/8 RtH & tag Wm. Circ @ trig rate of 550gpm Testing flow diversion system & I I I l decoding on tools - `100%. 1 11 /7/2007 11:30 11.50 11 /7/2007 23:00 'Drilling 9 5/8 1DrIg f/ 1455' V 2155'. 61fph pipe in ground. (130 ROP). P/U =125, S/0 =112k, Rot =120k. 5 -12k WOB. I 100- 120rpm, 6k torq. 9.1- 9.2ppg, 42visc, 550gpm @ 1800psi. I Tight @ 1841' - dragging @ 10k. Work pipe and wipe clean. Mixing & diluting mud system as needed to maintain 9.2ppg. 11 /7/2007 23:00 1.00111/8/2007 00:00 Dritkng 195/8 Hit hard drig © 2155' - make 1/2' and hanging up. Working pipe & 11 1 I backreaming stand - cant attempting to drill ahead. Drill to 2157' and drib 1 string hanging up. Cant work pipe & add lubricant to system. Push thru w/ 30k and cant ddg ahead, to 2157'. not working, had Quadco hand out to repair same replaced PLC - Totco PVT o rillin Rotate 9 5/8 11/8/2007 : 0 6.00 11/8/2007 06:00 I D 00 0 9 9. card. Drill F/ 2157' to 2550', 120 RPM, 4 -6 TQ, ROT WT 120, UPWT 125, DNWT 118, 525 GPM, 1800 PSI, WOB 5 -10, ROP 130, work pipe as needed. 1 I I Made connection and IBOP would not open. SLB out to service equipment, !AIM technologies cleaning cement silos for pad and spider jet inspection. 11/8/2007 06:00 3.50 11!8/2007 09:30 Drilflng Rotate 95/8 lDr F/ 2550 to 2750, 120 RPM, TO 4-6, ROTWI 125, UPWT 135. ` DNWT I 118, WOB 5-10, 130 ROP, 525 GPM 2000 PSI. Swab on #1 purr g aS 1 11/8/2007 09:30 1.50 11:00 Rig - Repair 9 5/8 1 RU circulating sub and hose to circulate and reciprocate while working on TDS. Work on TDS, found upper IBOP activation arm wore out and air hose to activate same disconnected, quick connects are wore out need to replace ! I I all on TDS system currently have quick connect wired were it will not open. 11/8/2007 11:00 1.00 11/8/2007 12:00 Drilling - Rotate 95/8 Change swab continue to drill to 2833', with one pump at 480 GPM rate. 1 11/8/2007 12:00 9.50 11/8/2007 21:30 Drilling - Rotary 19 5/8 DrIg f/ 2833' V 3572'. 78fph pipe in ground. 8 -12k WOB, 125rpm, 4k torq. ISteerable (one run) 1550gpm @ 1900psi. Dumping & diluting mud @ 50bph to keep weight down. 11/8/2007 21:30 1.50 11/8/2007 23:00 LWD 95/8 Pick test point and stop dtlg. Log up from 3572'V 3522' @ 8ofpll. Coat circ why working pipe - alg log data for test point. Set bit @ 3522' - TestTrak @ 3425' and test A2S formation. Circ 550gpm @ 1600psi. After download of data itappears that formation pressure is 510 PSI anticipated l pressure was 4941 PSI. Note aifter circulating hole clean and knocking mud 1 back a couple of points ECD dropp horn 10.5 to 10.1 11/8/2007 23:00 1.00 11/9/2007 00:00 Trip Out of Hole 9 5/8 I Begin POOH f/ short trip. P /U =150k, S /0 =110k, max overpull =l0k. Hole clean & free - no grabbing or sticking off slips. Second stand out found metal nng '' 1 i n mg on tool joint, cleaned up same for inspection, appears to be alluminum 1 material most likely from drill out portion of Davis Lynch stage tool/ packer. Pull 10 stands total 11/9/2007 00 :00 0.50 11/9/2007.00:30 Trip Out of Hole 8 1/2 Finish 10 std short trip - P /Um145k, S/0.118k, max overpuM =ltlk:. No ledges........ 1 1 or tight spots seen. 11/9/2007 00:30 0.50 11/9/2007 01:00 Rig - Service 8 1/2 Service TDS - swivel packing & IBOP. 11/9/2007 01:00 0.50 11/9/2007 01:30 Tripping in 18 RtH T13500', wash down to 3572', UPWT 132, DWT 128, 120 RPM, 12.5 BPM, 1800 PSI 11/9/2007 01:30 4.50 11/9/2007 06:00 Drilling - Rotate 8 1/2 1 Drill F/ 3572' T/ 3873', 120RPM, TQ6, RW140, UW 150, DW 130, 12.5 BPM 1 1850 PSI 11/9/2007 06:00 2.00 11/9/2007 08 :00 LWD 81/2 Log AS 3844' BD 3744' Tool Depth, 610 PSI tight - A33677' BD, 3570' Tool Depth 978 PSI tight - A5 3817' BD, 3720 Tool Depth, 532 PSI tight. 1 11/9/2007 08:00 6.50 11/9/2007 14:30 Drilling - Rotate 8 1/2 ,Drill F/ 3873' T/ 4236', 120RPM, TQ7 -8, ROT WT 142, 150 DW, 132'DW,12.5 ! 1BPM, 1900 PSI, 120- 140FPH, WOB 6 -8K, F 4112 -4122 ROP 20 -30, WOB , 1 10-15K 11/9/200714:30 1.00 11/9/2007 15:30 LWD 81/2 Correlate for tagging 828 sand. Set toot @ 4107', 4204' bit depth & test - 2?? 1 psi 1 11/9/2007 15:30 ! 2.00 11/9/2007 17:30 Drilling - Rotate 8 1/2 Ddg f/ 4236' V 4375'. 6 -12k WOB, 100- 140rpm, 8k torq. 550gpm @ 1900psi. 1 11/9/2007 17:30 I 1.00 11/9/2007 18:30 LWD 81/2 Comdata & logging 838 send. Set tool © 4254', 4351' bit depth & test - 1 11/9/2007 18:30 5.00 11/9/2007 23:30 Drilling - Rotate 8 1/2 D g p f// 4375' V 4620 49fph pipe in ground, 50 -90 ROP. 8 -12k WOB, 125rpm, 1 , 18k torq. 550gpm @ 1950psi. Hard drig f/ 4550' V 4600' - torq increase. ii Increased to 150rpm @ cleaned out. Cant ddg ahead no problem. 11/9/2007 23:30 0.50 11/10/200700:00 LWD 81/2 Baddog w/o rotary f/ 4551'6+ 4541' r? 80fph - correlate B5S formation. RIH & set string for 5 mitt- broke free w/ 20k. P/U to 4586' bit depth, 4489' toot depth 1 & test 658 - 368psi. 1111/10/2007 00:00 1.00 11/10/2007 01:00 LWD 18 1/2 Condition hole, pull log and perform test at 4586 Bit depth, 4489 tool depth 11/10/2007 01:00 6.00111/ 07:00 IDriikryy - Rotate 8 1/2 'Oda Fl 4620' to 4995. WOB 10K, Rotary speed 120, (62.6' PIGPH) I ! 11/10/2007 07:00 1.0011/10/2007 08:00 1 LWD 8 1/2 :Condition hole, pull log and perform test at 4951' Bit depth, 4854' tool depth. Cl sand 298 PSI 60.42 Mob. 1 11/10/2007 08:00 I 3.00 11/10/2007 11:00 Drilling - Rotate 18 1/2 Drill From 4995' - 5179', 120 RPM 10K WOB, 2100 PSI, (61.3' MPH) 1 11/10/2007 11:00 1 0.50 11:30 LWD 8 1/2 Condition hole, pull log and perform test at 5120 Bit depth, 5023' tool depth C3 395 PSI 36 MOB 11/10/2007 11:30 2.00 11/10/2007 13:30 Drilling - Rotate 181/2 Dry F/ 5179'-5285' 12k WOB, 125rpm, 8-10k torq, 550gpm @ 1900psi. 80- 100fph ROP. Hard spots w/ ash, quartz & sandstone, 10 -20iph ROP. 11/10/2007 13:30 0.501 11/10/2007 14:00 LWD 81/2 Backlog C5S & correlate test point - 5259 bit depth, 5162' tool depth. C5S 1 994psi, 16.5 mob. 11/10/2007 14 :00 0.5011l/10/2007 14:30 1Rig - Service 8 1/2 'Service TD - wash pipe & IBOP. 11/10/2007 14:30 4.50.11/10/2007 19:00 1 Drilling - Rotate 8 1/2 Drlg f/ 5285' V 5469'. 14k WOB, 100- 140rpm, 12k torq, 550gpm @ 1950psi. Sporadic tough ddg w/ ROP = 10fph, quartz/sandstone conglomerate. I S • Chevron Chevron - Alaska Time Log Summary Sort Well Name - - -- - -_- Field Name -.- - - -- API /UWI ---- - -_ - -- Lease/Senal --- TCHEVNO - License No. /Prope...l Orig KB Elev(ft...'. Water Depth (ft) 1 M -17 McArthur River Field 507332055200 ADL017594; LB2629 2071200 79.2 185.00 - Start Date (nn) 1 - - - End Date ' — Activity. -- -T lilf%Osp Sz j'..------ - -. - - Centerent our 11/10/2007 19:00 I 0.50 11/10/2007 19:30 Rig Repair 8 1/2 To p drive blower down - inspect lines & found wire rubbed raw - repair & tieback. Leaking hydraulic cylinder on pipe grabber - tighten & function, good. I 11110/2007 19:30 1 4.50111/11/2007 00 :00 !Drilling - Rotate 8 112 prig (/5469' t/ 5601'. 15-20k WOB, 80- 120rpm, 15k tons. 550gpm © 1950psi 1 !Harder drlg continuing w/ more frequent ash/quartz formations - 10- 15fph. 11/11/2007 00:00 3.00 11/11/2007 03:00 Drilling - Rotate 8 1/2 Drill F/5501 / 5710, 130RPM, TQ 11 -14, ROT WT 235, DN WT145, 12.5 , BPM, 2000 PSI. 11/11/2007 03:00 i 2.00 1 1/11/2007 05:00 Circulate & Condition 181/2 CBU, Pump wall nut sweep for flag, and to clean hole. Seen sweep back within 10 BBL of calculated volume. Continue to circulate until, hole was clean. 11/11/2007 05:00 6.501,11/11/2007 11:30 ,Trip Out of Hole 8 1/2 POOH from 5710' up wt 245, do wt 190, Tight at 4600' 35k over, could not Pumping !work through, pump out of hole from 4600 - 2800', attempted to POOH with out pumping with no luck. 2800 -1420 (9 5/8" shoe depth) POH without pumping. 11/11/200711:30 1.00 11/11/2007 12:30 Circulate & Condition 8 1/2 !Monitor static losses, loss 3 BPI -I, pump walnut sweep to clean hole. 11/11/2007 12:30 1.50,11/11/2007 14:00 1Trip Out of Hole 8 1/2 Finish TOOH U BHA. 11/11/200714:00 5.00 11/11/200719:00 1BHA - PU /LD 81/2 L/D Direc BHA - flex collars, unload sources from tools, L/D LWD equipment. Breakout bit & L/D Autotrak. 1 11/11/2007 19:00 1.50'11/11/2007 20:30 ' BHA - PU /LD 18 1/2 P/U BHA #6 - 8 1/2 " bit, NB stab, 6 -1/4" DC, stab, 2 6 -1/4" DC, stab, XO, & HWDP. 11/11/2007 20 :30 ` 0.50111/1.1/2007 21 :00 'Tripping in 1 1/2 RIH t/ shoe. , 1 11/11/2007 21:00 0.50 11/11/2007 21:30 Rig - Service 18 1/2 Service TD & fill pipe. 11/11/2007 21:30 i 2.50 11/12/2007 00:00 !Tripping In I8 1/2 TRIM at wiper assembly. P/U- S/Cm115k, Rot Wash & ream as ( necessary - tight spots O 2262, 2640, 2800, 2910.80rpm w/ 6k torq, 80spm 1 1 I@ 450psi. 111/12/2007 00:00 6.00 11/12/2007 06:00 Tripping In 8 1/2 TIH, RIH F/2992, work wash and ream tight spots @ 3315', 3354', 3423', 3674', 3689', 3778', 3804', 3874', 3804', 3911', 4164', 4885', 5145', 5375', :wash and ream last 3 stands to bottom @5710', 120 RPM, UPWT 215, 1 'DNWT 155, ROT 190 high visc around I1 1 11/12/2{)07 06:00 1.50 11/121200707:30 Circulate & Condition 8112 Circulate BU, 30 BBL walknut BBL sweep ole, 1 1 1 hole continues to be near gauge. eeP 2rou to dean s PWT 215, DNWT 150, work tight s ots 5430' 5105', 11/12/2007 07:30 3.50111/12/2007 11:00 'Tri Out of Hole 8 1/2 POOH F/5710' U p @ I Trip 1 15058', 4782', 4490', 4435', 4270', Pump through tight spot @ 3980', pull good ,from 3980' to shoe. Monitor well @ shoe 2 BPH Loss. 11/12/2007 11:00 1. 50111/12/2007 12:30 'BHA - PU/LD 8 1/2 I Lay down BHA stand back HWDP. Clean floor. 11/12/2007 12:30 2.50 11/12/2007 15:00 Wellhead - Install or 1 8 1/2 Pull wearbushing, took 22k to pull loose barred in, PU stand and wash 1 Retrieve Wear wellhead bowl prior to setting test joint. Drain stack. M/U test jt w/ test plug & ' Bushing washout stack. 1 1 11/12/200715 :00 3.50 11/12/200718:30 BOP - Nipple Up 81/2 Puff 5" rams & reolace w/ 7" cso rams in upper caviyt r. R/U test pump & chart recorder. Load csg tools to floor. 11 ! 1111/12/2007 18:30 2.00 11/12/2007 20:30 BOP Test - Surface 81/2 (Test 7" pipe rams U 250Lo, 4000Hi as per AOGCC. Pull test plug & UD test jI. 11/12/2007 20:30 1.00 11/12/ 2007 21:30 Casing - Rig Up / Rig 1 8112 Swap rig tongs & RAJ csg tongs - hook up power lines. Prep floor with loos & Down Running r centralizers. Equipment 11/12/2007 21:30 2.50 11/13/2007 00:00 Casing /Liner - 1 8 1/2 1PJSM. P/U 7" float shoe, 2 jt shoe track & float collar + 1 jt - bakerlock same. Running 1 Fill pipe & test floats - good. Begin RIH w/ 7" 26# L-80 BTC csg. 11/13/2007 00:00 7.00 11/13/2007 07:00 !Casing - Running 81/2 n 7" 26# L -80BTQ to 3550', filling each joint i centralizers as ! 1 prescribed !I 11/13/2007 07:00 0.50111/13/2007 07:30 1Circulate & Condition 8 1/2 Circulate a couple of BU clean and condition hole mud at 9.3# 65 visc 6 BPM at 300 PSI 1111/13/2007 07:30 4.50 11/13/2007 12:00 Casing - Running (81/2 !RIM W/ 7` casing TI 5638 MU casing hanger DNWT 140, UPWT 220 1 11/13/2007 12:00 4.50111/13/2007 16:30 Casing - Running 8 1/2 MU Hanger and break circulation, 25 SPM 270 PSI, set down @ 5633'. Work 1 I down varying pump rates from 2.5 to 5 BPM, looks like hanging up on I I ' centralizers, worked down to hanger landed in wellhead. Reciprocated pipe I i'wh_j(g maintaining 5 BPM rates pump pressures around 300 to 40n PSI, 11/13/230716 :30 f 1.00111/13/200717 :30 Cement - Rig Up / 81/2 Change form 5" DP pup 15' to 10' long on cement joint, MU Hallibttrton dart Rig Down Equipment drop sub see cement head, WO Iron roughneck. 11/13/2007 17:30 2.00111/13/2007 19:30 Cement - Rig Up / 8 1/2 Continue to circulate and condition hole while rigging up SLB cement iron on ,Rig Down Equipment rig floor II 111/13/200719:30 1.00 11/1312007 20:30 Cement - Mix/Pump 81/2 I Hoot PJSM , prior to cementing. pump 5 BBL H2O to NI and purge lines test 1 1 fines to 5000 PSI. had leaking chicksan SD and replace same 1 1 1 11/13/2007 20:30 2.00111/13/2007 22:30 , : Casing - Pressure 8 1/2 Pump 30 BL mud push down DP @ 5 BPM with rig pump, SLB followed with 1 1 ,Testing 143 BBL 12 PPG LITECRETE max rate of 3.8 BPM. Released Halliburton 1 !dad engaged wiper plug with 2 BBLS away pressured up to 2200 PSI before ,disengaging, pump 5 more BBL mud. (2 BBL cement and 5 BBL mud) Rig 1 pump took over and pumped total of 207 BBL 9.2 PPG mud to displace @ 6 1 , BPM rate. Final pump pressure was 1000 PSI, Mud push was seen at shakers within 2 BBL of bumping plug. Bumped plug and presured upp to 1 ;1500 PSI held for 5 minutes. Bled off pressure and checked floats 2BBL I retums. Cement in place @ 22:05 HRS. Had good returns throughout operation. MAX 10 BBL loss during displacement. 11/13/2007 22:30 0.50 11/13/2007 23:00 Cement - Rig Up / 81/2 CSLB test casino to 3500 PSI for 30 minutes and chart same 12 PSI loss took I Rig Down Equipment 13 BBL to pressure up. Shoe depth at 5700' 1 11/13/2007 23:00 1.00 11/14/2007 00:00 8 1/2 Start to rig down cementing equipment 11/14/2007 00:00 0.50 11/1412007 00:30 Casing - Rig Up / Rig 17 Finish R/D CSG running equipment - Back out lending joint & lay down double Down Equipment 1 sub. 11/14/2007 00:30 0.50 11/14/2007 01:00 1Casing - Rig Up / Rig 7 ;Clear & dean rig floor - Flush & drain stack. I Down Equipment 11/14/2007 01 :00 j 1.50111/14/2007 :30 !Casing - Rig Up / Rig 7 Wash out wellhead and stack W/ cementing joint. Set packoff & nun in lock screws Down Equipment down sc e - Tesf pads off 250 psi tow for 30 min &5000 psi high for 30 I min. (Good Test) 111/14/2007 02:30 1.5011/14/2007 04:00 I 'I Drill Pipe - Pick -Up / 17 UD landing joint & 9 -6" DC'S 1 Lay Down 11/14/200704:00` I 2.00:11114/200706:00 Rig - Cut &StipDritl 17 i ,Cut &SIip102'ofdritlline. Line I 41 111 . Chevron Chevron - Alaska OW Time Log Summary Sort Name Field Name (API /UWI , CHEVNO T pe... Ong Well Name Lease/Senal License No./Pro :ai KB Elev (ft. 'Water Depth (ft) M -17 McArthur River Field 507332055200 ADL017594; ! LB2629 2071200 79.2 185.00 _ Start Date I Dur (Be) i End Date Activity' a tICsg Sc — Comment 1 11/14/2007 06:00 2.00 11/14/2007 08:00 BOP - Change Rams 7 Change rams from 7" to 3-1/2" 11/14/2007 08 :00 5.50 11/14/2007 13:30 1Rig - Service 7 !Remove & replace back out ram on top drive, Change gear oil in top drive 1 ■ Remove 4-1/2" IF saver sub, Replace (BOP actuator stem, service & inspect top drive & draworks. 11/14/2007 13:30 1.00 11/14/2007 14:30 Rig - Service '7 Re- install 4 -1/2" saver sub, 4 -1/2" dies & head guide (3 -1/2" saver sub had to ! be sent in for OD reduction). 1 11/14/2007 14:30 1.50111/14/200716:00 BOP Test 17 (Started to test BOP found drip from annulus valve 11/14/2007 16:00 ! 1.50 11/14/2007 17:30 BOP Test 7 :Pulled test plug & installed a new seal, worked annular, reinstalled test plug, ! I pressure up & seat same. 11/14/2007 17:30 6.50111/15/2007 00:00 (BOP Test 17 on 5" & 3.5 ", (BOP (5" & 3.5 "), TIW (5" & 3.5 "), TD Valves, Choke Manifold, Stand pipe, 250 psi low - 4000 psi high. Test annular ! to 250 psi low & 3000 psi high on 5" & 3.5'. All tests completed with fresh water. 11/15/2007 00:00 2.00111/15/2007 02:00 ,BOP Test 1 7 ,Finish BOP test 11/15/2007 02:00 1.50 11/15/2007 03:30 'BOP Test 17 (Pull test plug & install 6-3/8" ID wear bushing - Stand back test stand. ! 1 11/15/2007 03:30 3.50! 11/15/2007 07:00 !,Rig Up / Rig Down"" 17 Remove 4 -1/2" saver sub & install 3 -1/2" saver sub - prep rig floor to P/U BHA. 11/15/2007 07:00 3.00 11/15/2007 10:00 'BHA - PU/MU" 161/8 'P /U BHA as per prog - download MWD & bad source. 11/15/2007 10:00 1.50 11/15/2007 11:30 Tripping In 6 1/8 TIN picking up 3 -1/2" HWDP & jars - Shallow test MWD @ 7.5 BPM -1500 psi, (good communication) 11/15/2007 11:30 4.00 11/15/2007 15:30 !Tripping In '6 1/8 I T1H WI 3-1/2" DP T/ 5,500' - Fill DP ® 27 SPM, 565 psi. (observed proper 'displacement values on TIH) P/U WT =160K, S/O WT =115 k, ROT WT = I130KTQ 'e6K@70RPM. I 11/15/2007 15:30 1.50 11/15/2007 17:00 Drilling - Rotary (With 6 1/8 Tag & drill CMT F/ 5610' T/ 5616' - Drill FC (5616' DPM), Shoe Track & Shoe Motor) (5, /08' UPM - 4,bb9' I VU) CM I drilled very quickly, held ROP to 145 FPH - ! Pumping @ 68 SPM - 290 GPM, 2400 psi. - 70 RPM - Drilled 20' of new formation T/ 5730' Formation drilled up was a Sand Clay Volcanic Ash material 11/15/200717:00 1.50 11/15/200718:30 Circulate & Condition 61/8 Circulate & Condition Mud in preparation for FIT - Pumping* 70 spm - 2500 I PSI. 1 11/15/2007 18:30 3.50 11/15/2007 22:00 'FIT/LOT"" 6 1/8 Fill lines, break circulation & pressure test lines to 2000 psi - Attempt #1 - in 1/4 bbl increments pressured to 1045 on DP only observing 930 psi on csg, ! 1 pressure broke back to 650 on DP. 2nd Attempt - Repaired backside gauge & ! 1 I added a new gauge to observe, pressured up again in 1/4 bbl increments :down DP with final pressure on DP 1040 psi & on CSG 880 psi, after 5 min, I CSG pressure = 855 psi - DP = 959, 3rd Attempt - decision to pressure DP to I :achieve 1045 psi on casing, @ 1 bbl pumped, observed 1040 psi on casing, after 10 sec, observed 1040 psi, after 5 min - 1040 psi. Accepted test, (13,5 , ppg EMW W/ 9.2 PPG Mud) - R/D test equipment. NOTE: MWD recorded a 14.05 MWE FIT test on there DH tools. 11/15/2007 22:00 2.00 11/16/ 2007 00:00 Drilling - Rotary (With 61/8 Drill ahead & survey F/ 5730' T/ 5869' - Avg ROP = 69.5' / hr - Avg Motor) instantaionus ROP = 130' - 145' / Hr. Drilling W/ 70 RPM, 2200 PSI, 6000 ft lbs torque. Max gas observed = 980 units Avg background gas = 45 units The 980 units was from around 5800' and it was from a sand per mud logger. 11/16/2007 00:00 3.00 11/16/2007 03:00 ! Drilling - Rotary (With 1 6 1/8 Drill F/ 5869 to 6185, 70 RPM, TQ 60, ROT WT135, Up 175, DN 118, 7 BPM, Motor) 12500 PSI 1 11/16/2007 03:00 1.50 11/16/2007 04:30 Drilling - 61/8 10611 Slide F/ 6185' to 6213' 7 BPM, 2500 PSI Directional/Orienting I 11/16/2007 04:30 2.50! 11/16/2007 07:00 Drilling - Rotary 6 1/8 1 Drill From 6213 to 6475, 70 RPM, 6 -7 TQ, ROT WT 142, UW 185, DW 120, 7 Steerable (one run) BPM 2650 PSI 11/16/2007 07:00 1 0.50 11/16/2007 07:30 161/8 Drill slide F/ 6475 to 6507. 7 BPM, 2650 PSI Directional/Orienting I 11/16/2007 07:30 ! 4.00111/16/2007 11:30 1 Drilling - Rotary (With 6 1/8 !Drill F/ 6505 to 6805, 70 RMM, 7 TQ, ROT WT 146, UPWT 185, DNWT 121, Motor) 17 BPM 3050 PSI 11/16/2007 11:30 ( 11.50 11 /16/2007 23 :00 Drilling - 161/8 Drill. slide & staves from 6805 to 7870' (NI TQ), Pumping © 7 BPM - 3050 DirectionalOrienting 1 PSI, Rot P/U Weight =165K, Rot 810 Weight = 150K, Straight pull - Up I 1 205K, DT = 130K, Rotary torque *70 RPM - 7500 Ft Lbs 11/16/2007 23:00 1.00 :11/17/2007 00:00 Circulate & Condition 6 1/8 1 CCM in preparation to POOH & run 5" production liner - Pumping @ 70 SPM I- 2950 psi. Initial B/U shakers approx 60% covered with cuttings. 11/17/2007 00:00 2.00111/17/2007 02:00 Circulate & Condition 61/8 Circulate and reciprocate pipe, 7 BPM 2750 PSI, pump 40 BBL nut plug { sweep, had small and large coals back. Had nut plug back early by 200 1 1 (strokes (20 bbl) 11/17/2007 02:00 2.00 11/17/2007 04:00 Circulate & Condition 6 1/8 Circulate and reciprocate pipe, 7 BPM 2750 PSI, pump 40 BBL high visc sweep, small coals and sand back. 11/17/2007 04:00 ! 2.00111/17/2007 06:00 Trip Out of Hole 16 1/8 POOH F/ 7670 to 5683', hole in good shape, seen a couple of bobbles no more than 30K that immediately . `130 DN release ! 1 rredleteiy 205 UW 11/17/2007 06:00 i 1.00 11/17/2007 07:00 Circulate & Condition L 6 1/8 At shoe CBU, 7 BPM 2650, Fill TT, and monitor well F/ static losses, none :seen. Pump dry job. 11/17/2007 07:00 ' 1.00111/17/2007 08:00 (Trip Out of Hole 61/8 (Trip out of hole, rig down Inteck auto I az manifold and hoses F/ rig floor , 11/17/2007 08:00 1.50,11/17/2007 09:30 ,Trip Out of Hole 6 1/8 POOH to BHA monitor well static. 11/17/2007 09 :30 1.00111/17/2007 10:30 (BHA - Handle" 6 1/8 'Stand back HWDP `and jars 7 stands total 1 11/17/200710:30 1.50 11/17/2007 12:00 (BHA - Handle" 6 1/8 LD flex joints, JSA -PJSM, LD NUKE sources, lay down 2 more flex joints, i prep to LD stab. 11/17/200712:00 3.00111/17/2007 15:00 (BHA - Handle." � 6 1/8 ' Down load tools, RD decoder and transducer. ' 11/17/2007 15:00 1.00 11/17/2007 16:00 !Rig Up / Rig Down" 16 1/8 Move HWDP to ODS rack 11/17/200716:00 I 1.00111/17/200717:00 Cement - Rig Up / 6 1/8 Prior to running casing, PU and tighten all connections on BOT rotating Rig Down Equipment cement head. 11/17/2007 17:00 1.50 11/17/2007 18:30 Liner - Rig Up / Rig I6 1/8 RU WOTCO tongs and JAM system, change handling equipment had PJSM Down Running ! with all hands Equipment 11/17/200718 :30 4.50111/17/2007 23:00 Liner - Running 1 /8 PU rit) Vt $" 18 FP L-89 513 HVdrill) t aai g with cementrelizers on each 1 ! I joint, initially had some problems with JAM-system but If worked it self out. 11/17/2007 23:00 1.00 11/18/2007 00:00 ! Rig - Repair 6 1/8 Had problems W/ shuttle valve on tongs, work boat, Trip Drill 1 Min 30 Sec. f • III Chevron Chevron - Alaska Time Log Summary Sort Well Name - -- Field Name API/UWI Leasse/Seral CHEVNO License No. /Prope...I Orig KB Elev (ft.. Water Depth (ft) M -17 McArthur River Field 507332055200 ADL017594; LB2629 2071200 79 2 185.00 11/18/2007 06:30 Liner - Running dumment Start Date Our (hrs) r End Date Activity i BitlCag Sz' _1 11/18/2007 00:00 , 6.50 6 1/8 Continue to TIH W% 5" 18# L -80 production liner - PIU Baker "ZXP" liner hanger as per on site Baker rep - Change handling tools & R/D Weatherford tongs - P/U pup jts & run 1 stand of 3 -1/2" DP - Establish P /U- (96K), S /O- (94K), ROT Torque @ 20 RPM -(1500 ft Ibs) & Pump Pressure values- (600 psi @ 80 SPM) of liner - Set torque limiter to 7500 ft lbs & continue TIH on 3 -1/2" DP T/ 5635' filling pipe every 10 stands. (Note: Drifted pipe with Drift) 11/18/2007 0630 ' 1.00111/18/2007 07:30 I Circulate & Condition 161/8 CCM 2 5635' - 6 born -1000 psi - P/U = 15K - S/O = 115K - Rot = 130K - 1 55nrf f trimly. (pump on) 11/18/2007 07:30 2.50'11/18/2007 10:00 1 1 Liner - Running 6 1/8 TIH F/ 5635 T/ 5770', Started taking weight, set down 15k, still unable to S/O I- Observed 20k overpull to P/U - Attempted to circulate, packed off, (pressured up to 1100 psi & did not bleed back) cannot P/U or S/O - Slowly worked free and nulled hack uo into the 7" casino shoe - Worked pipe inside 7" casing , slowly staged pump up to 5 BPM - CBU - Max gas observed = 11013 units, coal the size of aquarium gravel coming over shaker. 11/18/2007 10:00 ' 4.50 11/18/2007 14 :30 Trip Out of Hole 61/8 Decision made to pump out of the hole - POOH (pumping) F 5635" T/ 3866', 1 Pumping no trouble encountered, still unable to S/O with pump on. ■ 1 Note: Any attempt to 8/0 was futile. 11/18/2007 14:30 0.50 15:00 Circulate & Condition 1 ,6 1/8 Flow check well, observed small amount of flow (mud appeared aerated) CBU - Check flow, well static. 11/18/2007 15:00 1.50 11/18/2007 16:30 Trip Out of Hole 6 1/8 Continue to POOH W/ 5" liner to Baker ZXP" L/D same Inspection of Pumping h- • e . 'v ... 1ttwno to set Observed small pieces of coal around hanger element. 11/18/2007 16:30 4.00111/18/2007 20:30 Trip Out of Hole 16 1/8 'Held PJSM & HACL - POOH laying down the 5" production liner (45 jts) 11/18/2007 20:30 I 1.00111/18/2007 21 :30 Rig - Service 6 1/8 Held safety stand down and addressed incident with link tilt release, serviced rig & attended boat with required BHA components for cleanout rim. 11/18/2007 21:30 2.50 11/19/2007 00:00 Trip Out of Hole 16 1/8 Continue to POOH laying down 5" liner - Prepare to stand shoe track in the l derrick. 11/19/2007 00:00 j 2.00 11/19/2007 02:00 Rig Up / Rig Down** 161/8 Stand back 120' shoe track stand in derrick with tugger R/D Weatherford tongs from rig floor. 1 111/19/2007 02:00 3.00111/19/2007 05:00 BHA - PU /MU"" 6 1/8 'Stage cleanout BHA components to rig floor & M/U same as per BHA detail - IRIH W/ HWDP 11/19/2007 05:00 2.00 11/19/2007 07:00 Tripping In 161/8 RIH W/ 30 stands of 3-1/2" DP. 11/19/2007 07:00 1.00 08:00 Tripping In 6 1/8 Attempted to break circulation, unable In pump - Close annular & attempt to 1 ;reverse cm, pumping @ 3.5 BPM @ 450 psi (indicative of float being installed I lup side down.) 11/19/2007 08:00 2.00 11/19/2007 10:00 Trip Out of Hole 61/8 POOH 30 stands & BHA (wet) to bit - Break out bit, inspect & correctly jngtalt", float - Clean up rig floor. 11/19/2007 10:00 1.00 11:00 'Tripping In 1 6 1/8 ITIH W/ BHA & 3 stands of HWDP - M/U top drive & attempt to break 'circulation, cannot pump. 1 11/19/2007 11:00 1.50111/19/2007 12:30 (Trip Out of Hold. 6 1/8 1POOH & break out bit, observed bit pluboed:wclt chunks of rubber &Some al - Clean out bit & change jets to 3 -18'S 11/19/2007 12:30 1.50 11/19/200714:00 Tripping In 6 1/8 M/U bit TIH W/ BHA - Clean mud pump screens - Broke circulation @ 56 I '.. SPM - 400 psi. 11/19/200714:00 2.50 11/19/2007 16:30 Tripping in 161/8 (TIH breaking circulation every 1561606s - A145 stand observed a pump rate Iof 70 SPM / 1400 psi. 11/19/2007 16:30 1.50 11/19/2007 18:00 Circulate & Condition 6 1/8 ICCM weighting mud system up from 9.2 ppg to 9.5 ppg pumping @ 70 SPM - SPP now @ 1650 psi with 9.5 ppg mud. 11/19/2007 18:00 6.00 11/20/2007 00 :00 Wash & Ream 6 1/8 Vfa .h R Ream F/ 5700' 7/131r - Pumping 070 spm with - 2000 psi, Torque range between 5k ftlbs - 9k ft ills, P/U WT - 145K at the start to 165 at TD - S/O Wt - 125k to 145k. - Rot weight = 135k 1 11/20/2007 00:00 2.0011/20/2007 02:00 Wash & Ream 1 6 1/8 Hold PTSM w/ Nabors & Support Personnel. Review TIF Ream from 7,318' !to 70' @ 70 spm @ 2100 psi, 70 rpm. Back ream each stand. Torgue- Off - , 7500, On -8- 10,000. Washed & reamed to 7,670'. 11/20/2007 02 :00 I 2.00111/20/2007 04 :00 Circulate & Condition 61/8 Circ & Reciprocate. Pump 50 bbl Nut Plug sweep. Get back C 292 bbls. Circ total of 620 bbls.. 70 spm @ 2150 psi, '198 UW & 128 SO I 11/20/2007 04:00 1.50111/20/2007 1 05:30 Trip Out of Hole 1 6 1/8 Start to TOOH. SPR # 1 @ 30 spm @ 580 psi. SPR # 2 @ 30 spm @ 560 1 psi. Start to POOH to shoe. Observed 3 notable areas of torque / tight - 5,732' - 5,780', 6,145' to 6,160', 7,565' to 7,595'. Hole appears to be in Good shape. 205 UW, 130 SO 11/20/2007 05:30 0.50 11/20/2007 06:00 kCirculate & Condition 16 118 Pump Dry Hole Job. Blow down TD & Mud Line 11/20/2007 06:00 2.00 11/20/2007 08:00 1 Trip Out of Hole 6 1/8 Cont. to TOOH to BHA. Monitor well. Well is Static 11/20/2007 08 :00 1.50 11/20/2007 0930 (BHA - Handle 16 1/8 Stand MOP DP & Jars. & 1 std. L/D 3 Stabs &Bit sub & 2 jts of Drill I Collars. 11/20/2007 09:30 ! 1.50 11/20/2007 11:00 1 ( Casing - Rig Up / Rig 1 , 6 1/8 Hold PJSM on running csg. P/U 3 jts of the Shoe Track that was stood back I DownEquipment 1 w/ Tugger 11/20/200711:00 1.00 11/20/200712 :00 Casing - Rig Up / Rig 6118 R/U Weatheffi rti r e nnuirwnenet, Fie Trip Tank w/ clean mud. R/U Fill Up I I I Down Equipment line. Check Float- Ok. P/U 1 jt & prepare to Run Liner 11/20/2007 12:00 ( 8.00 11/20/2007 20:00 ,Casing - Running 6 1/8 ,Cont to GIN w/ 5" Liner. Liner Length is 2,193.35' 11/20/2007 20 :00 2.00 11/20/2007 22:00 Tripping In 61 /8 MN Cross over from 5" Litter to 3 1/2" DriilPipe. Cont to GIH w/ 37 stands of (drill pipe. Liner shoe Q 5,633' 11/20/2007 22:00 0.75 11/20/2007 22:45 1 Rig - Service 6 1/8 1Rig Service on the Top Drive Unit, Greased and serviced same 11/20/2007 22:45 025 11/20/2007 23:00 Circulate & Condition 61/8 Start Pump @ 11 spm. 250 psi. Rotarty @ 20 min @ 5-K torque. 148 P/U weight. 115 S/O weight. 11/20/2007 23:00 1.00! 11/21/2007 00:00 Tripping In 6 1/8 Cont 1 to GIH w/ stands of Drill Pipe. Observe weights & slack off while GIH. Liner shoe § 6,562'. No problems GIH. 11/21/2007 00:00 ! 0.50111/21/2007 00 :30 Safety 61/8 Held PTSM with Night crew. Reveiw TIF Ops. Go over Game Plan for the 1 Meetings/Drills Day. Day crew continued to RIH w/ Liner 11/21/2007 00:30 1.50111/21/2007 02:00 Casing - Running , 6 1/8 Cont. to P/U Stands of 3 1/2" Drill Pipe & GIH with Liner. Started at depth 6,562' @ 0000 hrs. Smooth operations till 7,223'. Normal S/O at 122 -K. Tagged tight spot. Set down to 115 -K. P/U to 205 -K. Pulled free. Lower down & went thru tight spot. Cont. to GIH. Kelly Up & wash last 60' to bottom. Tagged PBTD of 7,670'. Circ § 1 bpm § 200 psi. I • Chevron IWO Chevron - Alaska Time Log Summary Sort Well Name Field Name _ -- __ -- - -- API/DWI Lease /Serial CHEVNO 1License No. /Prope...' KB Elev (ft...', Water Depth (ft) M -17 McArthur River Field 507332055200 ADL017594; LB2629 2071200 79.2 ! 185.00 Start .Date our (pra) E a Dale -- twenty SR csg so l Comment -- 11/21/2007 02:00 1.00 03:00 Casing - Rig Up / Rig '6 1/8 R/U Baker Cementing Head. M/U CMT lines to CMT Head. Screw CMT Down Equipment head to Drill Pipe. 11/21/2007 03:00 1 4.00 07:00 Circulate & Condition 6 1/8 1 M/U Calcium Carbide Bomb. Start to pump at 1.4 bpm @ 300 psi. Increase rate to 2 bpm @ 325 psi. Calculated Surface to surface @ 2560 strokes. Get aas soike at 3200 stoke, s. 64 bbls over calculated. Work pipe while arc. P/U rt 205-K then drop's to 190-K, S/0 wt @ 130-K 11/21/2007 07:00 3.50111/21/2007 10:30 'Circulate & Condition 6 1/8 Start to bring rate up to 3 bpm (30 spm). Pumped 10 min then starts to pack toff. Slow rate down to 1 bpm. Pipe is stuck. Work pipe to 245 -K P/U & S/O to 100 -K. Hold 6000 Torque on pipe. itttemnt to work pipe free. . Work Vie. Got pipe to move. 11/21/2007 10:30 1.50111/21/200712:00 1Circulate & Condition 6 1/8 Pump @ 1/2 bpm 0 150 pSi, Cont. to reci ine Work rate to to 6110 I bpm @ 180 psi. Slowly star(tic geErate up to 9/10 bpm @ 200 psi. 1 bpm 220 psi. 1 3/10 bpm @ 300 psi. P/U wt @ 210- K. S/O wt @ 130. Conti to Work pipe. 11/21/2007 12:00 3.50 11/21/2007 15:30 !Circulate & Condition 6 1/8 Cont to attempt to get rate up to 2 bpm. P/U wt @ 205 -K, then drops to 190 -K for steady pull. S/O @ 130 -K. Start @ 1.3 bpm @ 277 psi. 2 bpm @ 330 psi. If the Pipe wont go back down then just shut off the pump, Torque to 15000 ft - lbs and the pipe will GI H. Consistent pattern. P/U of 205 -K, drops to 190 -K while pulling on pipe. S/O @ 130 -K. If pipe wont go down. Just (repeat pattern of shutting down the pumps. Rotate 3 1/2 tums and lower down. 11/21/2007 15:30 2.00111/21/2007 17:30 Work Pipe 61/8 !Shut down Pumps- Put 2 gallons of marker dye & Calcium Carbonate Gas (bomb in Drill Pipe. Pam 14 strokes and the DP and stuck a could not afoul*. Work pipe to 250 P/U & S/O @ 110-K. ry with pressure on & , w/o pressure. Put 5-K torque on DP & work pipe. Try torque W/ pressure & w/o pressure. Take pressure up to 1000 psi & attempt to free pipe. 11_12_1 variations of torque & pressures in attempt to free pipe. No Luce; 11/21/2007 17:30 0.50 11/21/2007 18:00 ! Work Pipe 6 1/8 1 Hold 8500 Torque on DP. 0 psi DP. Start to pull on DP. Start @ 250 -K and ,work to 300 -K pull. Pulled at 300 3 times Drill Pipe is free. P/U @ 210 -K & drops to 200 -K, S/O @ 130 -K. Work nine 11/21/2007 18:00 I 2.00 11/21/2007 20:00 Work Pipe 6 1/8 1 Cont to work free pipe. Start to arc. Once the pipe was free, then we could arc. Start @ 1/2 bpm @ 145 psi. Wok rate to 1 bpm 250 psi. P/U r 205-K, S/O @ 130 -K, Attempt to rotate pipe, No luck. 1 turn @ 4500 TO, 2 tans @ 5000 TQ, 3 turns 0 6500 TQ, 5 turn @ 7500 TQ, 6 turns @ 8500 TO. Pipe will not rotate. Work pipe 205-K & S/O @ 130 -K. arc @ 1 barn 1 ®, 250 psi. 11/21/2007 20:00 2.00 111/21/2007 22:00 Work Pipe 6 1/8 Pipe is stuck. Can still circ but not move same. Work pull to 350 -K, No luck. 1 , , Ciro @ 1 bpm @ 280 psi. Pipe is stuck 1 jt up. Only 5' of travel. Cont to work pipe. No luck 11/21/2007 22:00 0.25 11/21/200722:15 Safety 6 1/8 1Hold PJSM W/ Nabors crew. Review TIF Ops for the ant job. Go over the Meetings/Drills I game plan for the cmt job. Schlumberger is preparing their equipment for the (cmt lob. Circ @ 1 bpm ®■ 210 psi. 11/21/2007 22:15 0.50, 11/21/2007 22:45 Work Pipe 16 1/8 Cant to work pipe at 350 -K P/U wt & 110 S/O wt. No Luck, Pipe is stuck. ,Circ @ 1 bpm @ 210 psi 11/21 /2007 22 :45 0.75111/21/2007 23:30 Casing - Rig Up:/ Rig 61/8 Shut down pump. L/D 1 jt that was stuck above the rotary table. M/U the 1 I Down Equipment ant treating fines to the manifold. Liner 14CR @ 5472', Liner Shoe @ 7637', 1 11/21/2007 23:30 0.50 11/22/2007 00:00 Circulate & Condition 6 1/8 ',Start pump back up. 1 bpm @ 375 psi. Schlumberger is still working on getting their equipment & materials on line. 11/22/2007 00:00 1.20 11 /22/2007 01 :12 Circulate & Condition 61/8 (Held PTSM w/ Nabors crew. Review TIF Ops. Go over the Game plan for the day. NIght Nabors Crew continued to arc • 1 bpm @ 325 psi. Cdr n ,,, "mw pipe nr instate Schlumberger continue to prep for ant job. 1 ,11/22/2007 01:12 2.001111/22/2007 03:12 Cement - Mix/Pump 6 1/8 .Shut down Rig Pump. Close TIW valve. Open cmt treating line. Pump S bbls, ! 1 of CW 100. Shut down. Test CMT treating lines to 250 -5000 psi - ok. Open ,valve. Pump 5 more bbls of CW 100. Pumped @ 1.776 bpm @ 450 psi. M & P 49.5 bbls of LXT cement. Mixed @ 15.8 ppg. Pumped cmt @ 1.8 bpm • I Pressure varied f/ 475 psi at the start of the job to 950 psi @ w/ 26 bbls gone. Shut down pumps. Switch to 1 bbl of CW100 & pump same. Shut down. Drop Baker Dart. Pump 4 bbls of CW100 @ 1.8 bpm @ 50 psi. Switch to 9.5 ppg mud. Catch fluid, then Pump @ 1.7 bpm. Pressure goes , from 125 psi to 2100 psi when dart hits the 5" liner. Cont to pump. Pressure ,increasing from 2575 psi to 3150 psi when 68 bbls of mud displaced. Bump , plug w/ 69 bbls gone @ 312 AM. Pressured up to 4500 psi. Held 5 min. ,Check floats. Got back 1 1/2 bbls. Floats are holding. Shoe depth (d 763f. ! Float Collar @ 7592', LC @ 7549', Top of Liner GD 5472' 11/22/2007 03:12 0.30 11/22/2007 03:30 Cement - Rig Up / 161/8 R/D CMT line from Baker CMT Head. P/U on DP to 150-K, 30-K over pull. I Rig Down Equipment Pipe released from the HGR. Set 20 -50-K down on ZXP. No indication of ZXP set. Neutral wt @ 130 -K. Again- Set 50,000 lbs down on ZXP . I indication of 7XP is oat, P/U a total of 9' & slacked off to 80-K, No' of ZXP shear. Made 5 attempts - 11/22/2007 03:30 1 1.50.11/22/2007 05:00 Circulate & Condition I6 1/8 Start to Circ at 10.5 bpm @ 2850 psi. Got bottoms uD. No cement to _ surface, Did recover huge amount of coal fines over the shaker. At times ,4 -6" thick over the shaker. Circ 3 1/2 BU. Circ well clean. 11/22/2007 05:00 1.50 11/22/2007 06:30 Rig Up / Rig Down"' 61/8 LID Baker CMT head & 2 singles. Wash out same. Blow line down to CMT 1 wash tank, Help Schlumberger CMT crew wash up & R/). 11/22/2007 06:30 3.00 09:30 Trip Out of Hole 6 1/8 Start to TOOH w/ 3 1/2" Drill Pipe. Rack back same. Baker tool @ surface. Dog Sub was not sheared. L/D Baker Running tool. 11/22/2007 09:30 I 1.00 11/22/200710:30 !Rig Up / Rig Down" 161/8 UD2 pup its. Soft break Hanger Assembly & L/D. Soft break the Baker CMT head Assembly & L/D same. 11/22/2007 10:30 1.00 11/22/2007 11:30 Rig Up / Rig Down`" 6 1/8 Move 7 stands of 3 1/2° HW Drill Pipe & 1 stand with Jam to Left side of derrick • • Chevron Chevron - Alaska y Time Log Summary Sort M __ _ -__ _ _ � I _ __ Start Date 9 WatDepth (ft) Well 17 me McArthur River Field 507332055200 'ADL017594 LB 629 2071200 /Pro a 79.2 "(R er Depth -- T A . p ��� 4 - - - -- -- Comment .._ `. Our (hhral End Date ctlNy' 11/22/2007 11 :30 3.00 11/22/2007 14:30 Rig Repair 6 1/8 Prep Rig floor to LID 5" Drill Plpe. Had to work on the Iron Roughneck. Unit will not tilt when at the Mouse Hole. Replaced 3 electric switches. Replace Isolonoid on the tilt Rig electriacan working on same. Crew is R/D the DD tongs for shipment to the Anna Platform. General cleaning up around the rig ,floor. Working on cleaning up the shaker & pump rooms. LID csg handling tools. 11/22/2007 14:30 ! 2.00111/22/2007 16:30 Drill Pipe - Pick -Up / '6 1/8 [Start to [JD 5' HW Drill Pipe. 17 jts. 1 set of 61/4" Jars Work on one stand Lay Down at a rune 11/22/2007 16:30 4.00 1 11/22/2007 20:30 I Rig Up / Rig Down" 6 1/8 Schlumberger Wire line Unit arrives. Spot & start to R/U same. Schlumberger just has 2 crew members. Rig crew assisting in the R/U. M/U 1 11/16" Cement Bond Logging tool. R/U equipment. 11/22/200720:30 3.50111/23/2007 00:00 'Log - Cased hole 61/8 Start GIH w/ 1 11/18' anent Bond Lao. Get on depth. TD C 7,548'. Log to i 5,472'. Too of CMT R9 7.04Q'. Start to POOH. Ran : SCMT /GR/CCL/Temp/Press tool 11/23/2007 00:00 1.50 11/23/2007 01:30 1 Log - Cased hole 6 1/8 Finish Pooh w/ SLB - SCMT /GR/CCL/Temp /Press tool & r /dn E -line 11/23/2007 01:30 2.00 11/23/200703:30 [Rig Up / Rig Down "' 61/8 Ft/dn DD tongs & remove weight from counter weight buckets & hang DB tongs - repair air leak on drillers console - dress air slips for 5' - drain stark to !, ( I mud cross - move E -tine unit away from cat walk - clean upper well bay room ■ 1 11/23/2007 03:30 0.50 04:00 : Safety 61/8 PJSM on moving lay /out & strap of 3 -1/2" BTC completion string & Udn of 5" 1 Meetings/Drills dp II I. 11/23/2007 04:00 3.50 11/23/2007 07:30 Rig Up / Rig Down"" 16.:1/8 Move 188 jts of 3-1/2° btc tbg f /center deck t/ south pipe rack. Stack & Strap same & move 5" HWDP to center deck - Prep to L/dn 5" dp 11/23/2007 07:30 7.00,11/23/2007 14:30 Drill Pipe - Pick -Up / 1 6 1/8 Udn 219 jts of 5" dp & load same on boat Lay Down 11/23/2007 14:30 Ir 150111123/2007 16 :00 Tripping In 161/8 [RIH w /20 jts of 3 1/2" HW & 63 jts of 3 t /2" DP . 1 111/23/200716:00 2.50111/23/2007 18:30 1 Drill Pipe - Pick -Up / 6 1/8 UD 63 jts of 3 1/2" DP. Loaded out on boat I Lay Down y 11/23/200718:30 2.00 11/23/200720:30 Drill Pipe - Pick -Up / 6 1/8 L/D 20 jts of 3 1/2" HW OP. UD 3 43/4' Doll Collars. Load out same on Lay Down boat 11/23/2007 20:30 3.50111/24/2007 00:00 Rig - Service 6 1/8 General clean up & organize Rig. Pull 2 7/8" Rams from storage. Replace lights in derrick. Clean conexs. Start to clean mud tank # 7. Cont to prep rig 'for next phase of operations. 11/24/2007 00 :00 12.00 11/24/200712:00 Rig - Service 61/8 Cant to do Rig maintenance & general clean up of rig. Replaced the light bulbs in the NW corner of the Rig, Clean deck. Spot Schlumberger WL unit on Pipe deck. Clean Pit No 7. Prep mud boxes for boat return. Off load boat with 72 jts of 2 7/8 "DP & 12 its of 31/2" Drill Collars. Strap same. Unloaded baskets of handling tools. Load out mist Mud material not needed. Clean upper Well Bay. Load Rig floor with 2 7/8° handling tools. Pull wear bushing. kW 2 718" Test joint. Drain stack. Set test Plug. Change out Lower rams to 2 7/8" rams, FM stack with water. Pump thru the test manifold. 1 Bleed out trapped air. 1 :11/24/2007 12:00 3.50 11/24/2007 15:30 BOP Test 6 1/8 Test Pipe rams to 250 -4000 psi - ok. Test TIW valves to 250 -4000 psi - ok. 1 l earmarinasre z5u - 4u0U psi - ok. LID test jt. LID test plug 1 11/24/200715 :30 2.50 11/24/2007 18:00 Rig - Service 61/8 Install Wear bushing. WU tongs for 2 7/8" pipe. Counter balance for safe 1 operations. OD /ID all BHA items. 11/24/2007 18:00 1.50 11/24/2007 19:30 1 BHA - PU /MU" 6 1/8 M/U 4 1/16" Bladed Mill, CSG Scrapper. Junk Basket, ox, 3 3 1/16" Drill ' collars, BHA @ 100.93'. 1 11/24/200719:30 3,00 11/2412007 22:30 Drill Pipe - Pick -Up / 61/8 P/U 2 7/8' DP off of pipe rack. Rabbit same. Run 69 jts of DP EOT @ I Lay Down 2,259.3Z 1 11/24/2007 22:30 0.50 11/24/2007 23:00 Rig Up / Rig Down" 61/8 ( Switch elevators. M/U XO. Prep rig to strap 3 1/2" Drill pipe in derrick. P/U 1 stand. Strap same. M/U in to 2 7/8" XO. 1 11/24/2007 23:00 0.50 11/24/200723 :30 Circulate & Condition 61/8 RN to break tint @ 2,259'. Cite @ 3 born @ 1250 psi. Ciro 18 blots. Shut down pumps. Side Note. Well is drinking about 1 bph rate for the day. 111/24/2007 23:30 0.50111/25/2007 00:00 Tripping In 6 1/8 Cont to GIH w/ 3 1 /2" Drill Pi a , Strap GIH. Bit @ 3462' @ 0000 hrs 1 1 11/25/2007 00:00 3.50 11/25/2007 03:30 Tripping In 61/8 Cont to RIH w/ 31/2" Drill Pipe filling every 10 stands & SLM t/ 7460'. No 1 : problem with Liner Top. 1 11/25/2007 03:30 1.00 11/25/2007 04:30 :Wash & Ream 6 1/8 Kelly up & wash @ 4 bpm @ 1400 psi f/ 7460' t/ 7545' & tap landing collar 1 11/25/2007 04:30 3.00 11/2512007 07:30 Circulate & Condition 6 /8 Circ & cond & reciprocate pipe - Adjust MW f/ 9.6 ppg t/ 9.5 ppg recovered +- 1/2 bbls fine over shakers - 170 up wt & 120 do wt :11/25/2007 07:30 1.00 11/25/2007 08:30 Circulate & Condition 1 6 1/8 Flow chk (ok) - Pump dry job - blow dn lines I 1 I 11/25/200708 :30 2.50 11/25/2007 11:00 Trip Out of Hole [61/8 Pooh w /3 -1/2" dp 11/25/2007 11:00 3.00 11/25/2007 14:00 ( : Trip Out of Hole 61/8 Chg handling tools - Pooh w/ 2 -7/8" dp & 3 -1/8" dc p /up nubbins - chk & I /dn i bha (ok). No debris in Junk Basket. 11125/2007 14:00 10.00 00:00 (BOP Test 61/8 Start to Test BODE: PN te st tools. R/tf & Pull the Wear Bushing. Install the Test Plug. Bu te st plug for 31/2'. R/U Test manifold. Stump test the (BOP valve. No test. Valve is leaking. Attempt to test the annular. No test. Determined that the test plug is leaking. Pull same. Wash stack. Install : I new 0 -Ring on test plug. Retest annular on the 31/2"to 2503000 psi - ok. I. Rebuild !BOP. Test 31/2": Rams & Kill & Choke `lines & valves & NCR 1 I valve & upper & kwveF (BOP & 14 choke valves all to 250-4000 psi -ok. i 11/26/2007 00:00 2.50 11/26/2007 02:30 BOP Test 16 1/8 1 Continue test Bops tested blinds 250 -4000 psi (ok) - M /up 2 -7/8" test jt 11/26/2007 02:30 1.50 11/2612007 04 :00 BOP Test 161/8 Attempt to test annuluar on 2 -7/8" (fails @ 2250 psi) - test TM/ valve & pipe rams (ok) - preform koomey test (ok) 1 1 1 11/26/2007 04:00 1.00 11/26/2007 05:00 BOP Test 61/8 1R/dn test jt - blow dn choke & lines 11/26/2007 05:00 14.50 11/26/2007 19:30 Rig - Repair 61/8 Nipple do pitcher nipple - remove annular latch cap - remove & re place element (Ser # 1302 - Traceability code 80NBRD803- 1303)XKM) - nip/up pitcher nipple - install test plug & 2-7/8" - till stack - faction Bag several times 11/26/2007 19:30 1.00 20:30 i BOP Test 61/8 Test hydril w/ 2 -7/8" 250 - 3000 psi (ok) 11/26/2007 20:30 1.50111/26/2007 22:00 BOP Test 16 1/8 (Pull test plug & set wear ring - r /dn test equipment 11/26/2007 22:00 1.50 11/26/2007 23:30 Log - Rig Up / Rig 6 1/8 M /up 3 -1/2" dp lubricator - Safety meeting & review explosive chk list Down 11/26/2007 23 :30 0.50[11 /27/200700:00 (Log -Cased hole 16 1/8 1R/up SWS E -line • • Chevron Chevron - Alaska OW Time Log Summary Sort Well Name Field Name API /UWI Lease/Serial CHEVNO License No. /Pmpe_. Ong KB Elev (ft... 1 Water Depth (ft) M -17 McArthur River Field 507332055200 ADL017594; LB2629 2071200 79.2 185.00 Start .Date �ur T End Date ActlVty I Bitten! Szi Co mment_ 1 ' O - -- --- - - - - -- 1 11/27/2007 00:00 1.00111/27/2007 01:00 Log -Rig Up / Rig 5 M/U bridge plug on WL & finish R/U. Down 11/27/2007 01:00 j 3.00111/27/2007 04:00 Log GR/CCL ' 5 i RIH w/ BP & correlate W/ CBL/GR/CCL on 11/22/2007 - set Ql 6260' WLM. 1 I '00H & W same. 11/27/2007 04:00 3.50,,11/27/2007 07:30 Perforation - Initial 5 M/U 2.5" perf gun w/ 6 spf - 36 total. RIH & correlate on depth @ 6234'. Pirf 6294' - 6240' no immediate losses. POOH monitoring losses < 1 bph. L/D guns. 11/27/2007 07:30 I 2.50 11/27/2007 10:00 f Log - GR/CCL 15 M/U cement retainer & RIH. Set C81 6216'. POOH.. Losses still < lbph. , 11/27/2007 10:00 1.0011/27/2007 11:00 I Log - Rig Up / Rig 5 UD tools & R/D wireline equipment. 1 Down i 11/27/2007 11:00 1.00;11/27/2007 1BHA - PU /MU'" 5 IC/0 handling tools. P/U std & M/U stinger assembly on 2 7/8" DP. 11/27/2007 12:00 3.50 11/27/2007 15:30 Tripping In 5 1RIH w/ stinger t/ 6200'. P/U = 140k, S/O = 115k. 11/27/2007 15:30 0.50 11/27/2007 16:00 !Circulate & Condition 5 Establish circ rates above retainer. lbpm © 85psi, 2bpm @ 175pst, 3bpm © 420psi, 4bpm @ 760psi. 11/27/2007 16 :00 2.00 11/27/2007 18:00 'Circulate & Condition 5 Stab into assembly & attempt to break circ. Working pump rate. Initiallly .5bpm @ 475psi around ZXP. Cont working pump rates to max of lbpm @ 500psi - acting packed off. Cont surging - able to maintain .7bpm @ 500psi. Circ total of 5obbls past top of liner hanger - 7bbls lost. 11/27200718:00 2.00111/27/2007 20:00 Circulate & Condition 5 Pull out of stinger & CBU. Lo H2S alarm © 40bbts away. Shutdown & check t l - Igkijnp. Shut -in & prep to cac thru choke. Gag pressure'�D. Can cac� bins up thru choke/gas buster no H2S, LEL over 30. Finish dm 1 12 times tams up w/ 35spm @ 500psi. Open bag & check for flow - static. 11/27/2007 20:00 1.00,11/27/2007 21:00 Circulate & Condition 5 CBU lx @ 5.Obpm, 110opsi - minimal small coal across shakers. 11272007 21:00 3.00[11/28/2007 00:00 Trip Out of Hole 5 Blow down manifold & gas buster w/ monitoring well - static. Pump dry job & begin POOH 1/ 2 7/8" DP s EOT. 11/28/2007 00:00 1.50111/28/2007 01:30 �Trp Out of Hole 5 POOH lay down 1 joint 2 7/8" drill pipe 111/282007 01:30 2.50 11/28/2007 04:00 Tripping in 5 RIH to 6,116` P/U 2pup joints 12' & 4.7' pickup RIH tag retainer P/U 140 K S/0 114`1< 11/28/2007 04:00 2.00 11/28/2007 06:00 Circulate & Condition 5 Circulate 5 BPM =950 PSI 6 BPM =1,500 PSI 6.5 BPM =1,750 PSI 1128/2007 06:00 ( 2.00 [1128 /2007 08:00 Circulate & Condition 5 Attempt to circulate 5"XOH amulets start out .7 BPM @ 750 PSI being up to 1 BPM would not circulate. Unsling from retainer dose annular preventer pressure up to 1,000 PSI bled back to 900 PSI no bleed off 11/28/2007 08:00 2.00111/28/2007 1 10:00 Circulate & Condition 15 ISting back into retainer circulate .8 BPM @ 750 PSI bring pump uo to 1 BPM 1 1Pressure up unsting 1 Presure up on back side to 1,500 PSI did not take any fluid sting back in 21 strokes 950 PSI solid Bleed off presure and unsting circulate to make sure stinger was ok circulate OK. Sting back into retainer attempt to presure up to 1,500 PSi injecting @ ,.5BPM 1,450 PSI 11/28/2007 10: 1.0011 8/200711:00 Circulate & Condition 5 U from retainer circulate bottoms up 2.5 times ;@ 6.5 BPM 1,750 PSI � !2 Unsling mix lime in mud I 11/28/2007 11:00 0.50 11/28/2007 11:30 Circulate & Condition 15 Close annular preventer bring up to 3,000 PSI bled back to 1,425 PSI and 1 held pressure back to 3,000 PSI bled back to 1600 PSi 1128/200711 :30 0.50111/28200712 :00 Trip Out of Hole 15 I Mbx dry job. R/D circ head. Rack back stand & L/D 2 pup jts. Pump slug. 11/28/2007 12:00 3.00 11/28/2007 15:00 Trip Out of Hole 5 POOH w/ stinger. Rack back all 2 7/8" DP. 11/28/2007 15:00 0.50 11/28/2007 15:30 Rig - Service 5 tService TO, swivel packing & drawwaks. 11/28/2007 15:30 2.50 11/28/2007 18:00 Tripping In 5 P/U rotating dog sub & RIH w/ 3 1/2" DP. 11/28/200718:00 i 1.0011128/200719:00 Casing - Pressure 5 Tag hanger @ 5472'. P/U =140k, S/0 =112k. Slack off 20k & ZXP sheared W/ it I Testing clear wergild indication. Slack off 40k & P/U. Flee w/ no overpufl. R/U chart recorder&p p ressure test liner ham w/ rig pumps. Pump 3bbts & pressured I, up to 35O0psi. Held mm - 4 11/28/2007 19:00 1 1.00 11/28/2007 20:00 Circulate & Condition 5 Finish mixing slug while circ @ 7bpm, 1200psi. Pump dry job. 11/28/2007 20:00 i 2.50 11/28/2007 22:30 Trip Out of Hole 5 POOH & L/D dog sub. Break down 3 12" stand for lubricator. Clean floor & send tools to deck. 11/28/2007 22:30 1.50111/29/2007 00:00 Log - Rig Up / Rig 5 PJSM & explosives checklist. R/U wireline sheaves & stab lubricator jt. P/U Down tools & M/U lubricator. Pull tools to floor & put rig on radio silence. 1 1129/2007 00:00 0.50 11/29/2007 00:30 Log - Rig Up / Rig 5 Finish arming pert guns & Mitt lubricator. Down 11/29/2007 00:30 2.00 11/29/2007 02:30 Perforation - Add 5 RIH w/ 6' 2.5" gun w/ 6spf - 0.64" shots. Tie in w/ marker jt @ 5750' on cmt eval log 11/22/2007. Run in to 5905' & ensure correct depths. P/U & fire guns / w/ top shot Cry 5782'. POOH w/ no overpull. All shots fired. , 11/29/2007 02:30 1.00 11/29/2007 03:30 Log- Rig Up / Rig 5 IUD tools & RID wireline. Down 11/29/2007 03:30 0.50 11/29/2007 04:00 BHA - PU /MU" 5 P/U stinger & M/U on 2 7/8" DP. 11/29/2007 04:00 3.00 11/29/2007 07:00 tripping. In 5 [RIH w/ 312" DP & P/U 2 pup jts. P /U =145k, S /0 =115k. 11/29/2007 07:00 1.50 11/29/2007 08:30 Circulate & Condition 5 1Wash last stand to top of retainer & CBU. Break out connection & swap lines to circ head. 11/29/2007 08:30 1 1.501129/2007 10:00 Circulate & Condition 5 Spot 5bbl 75visc sweep in 5" x 2 7/8" annulus, Sting into retainer & attempt to arc. 6slks away- 1000psi, 8stks away- 1500psi w/ no returns. Pull out of retainer & close bag - pressure annulus to l000psi & shut in - no pressure I drop. Bleed off. 11/29/2007 10:00 2.00 11/29/2007 12:00 Circulate & Condition 5 Stung back into retainer. Break circ @ 1bpm, 650- 700psi. With 17.5bbls away, pressure increase to 1300psi & then broke back to 1100psi. 1129/200712:00 I 1.50 11/29/2007 13:30 !Circulate & Cond"alon 15 Unsling from retainer & CBU coal back across shakers w/ hi -vise pill. Close 1 bag & pressure up to 15O0psi. Bleed off. Spot second hi -vise pin in 2 7/8" x 5" annulus above retainer. 11/29/2007 13:30 1.00 11/29/2007 14:30 ' Cement - Mix/Pump 5 Mix 20bbls 15.Bppg LXT cmt. Pressure test lines to 5000psi. , ( Q 11/29/2007 14:30 1.00111292007 Cement - Remedial 5 Pump 2bbls wash water. Begin pumping 16.5bbis 15.8ppgTXT cmt C ■ V 2.Obpm.. Pressure surging from 1500 to 170Opsi and breaking back 10 BBLs away started to inject 2.5 BPM @ 1,650 PSI when chem flush hit formation regained full circulation lost pressure to 650 PSI last 10 BBLs no returns i • Chevron Chevron - Alaska Time Log Summary Sort Well Name Field Name API /UWI Lease/Serial '.CHEVNO '..License NO./Prope... ',Ong KB Elev M.. Water Depth (K) '. M -17 McArthur River Field 507332055200 ADL017594; LB2629 2071200 79.2 185.00 start Date LOW (ha) i End Oats I Activity I BltICsg Sz L. - -- Comment 11/29/2007 15:30 ! 1.00 11/29/2007 16:30 ',Circulate & Condition 5 Unsting from retainer & CBU @ 6.5bpm, 1500psi.5 -6 BBLs cmt retums.dumped 20 BBLS contaminated mud 11/29/2007 16:30 1.00111/29/200717 :30 ♦Trip Out of Hole 5 POOH slow I/ 5828'. P /U= 140k,, S /0 =115k. R/U cmt lines. 11/29/2007 17:30 0.50 11/29/2007 18:00 Cement - Mix/Pump '5 Cont circ hole clean. Mix 10bbls for cmt plug @ 5828'. 11/29/2007 18:00 0.50 11/29/2007 18:30 !Cement - Remedial 15 !Shutdown & swap lines. Close pipe rams & open choke to shakers. Pump 7bbis water ahead. Pump 7bbis 15.8ppg LXT cmt @ 2.Obpm, 950psi. Pump lbbl water chaser. Begin displace w/ 9.5ppg mud from active system @ 2.Obpm 850psi - 32.5bbls total displacement. Holding 250- 300psi @ choke j 1thru entire job. Breakoff lines, 11/29/2007 18:30 0.50 11/29/2007 19:00 ( Trip Out of Hole 5 POOH above liner top U 5466'. Plug balanced - pipe pulling dry & maintaing :fluid level on backside while pulling pipe. R/U ark head. 11/29/200719:00 ' 1.00 11/29/2007 20:00 Cement - Squeeze 5 Close oloe rams & bean squeeze. Bring ant pump on C •Sbpm. lbbl gone, Pert 500psi. 26ol gone, 900psi. Pump lbbl extra,1000pst. Shutdown & monitor pressure • drop to 850psi & holding. Pump .5bbl @' 1000psi - slight break in pressure (appeared to be injecting). Shutdown & monitor pressure - drop to 400psi & holding. Talk w/ town - decide to pump lbbl more. Bring pumps © .5bpm & squeeze lbbl away it 900psi. Shutdown - pressure drop to 450psi & I hold for 15min. Bleed off pressure -!bbl back. Total pumped: 4.5 bbls. Est squeeze vol: 2.Obbls. 1 11/29/2007 20:00 1.50 11/29/2007 21:30 Circulate & Condition 5 ,P/U stand & break circ @ 6.5bpm, 1500psi. Begin washing slowly t/ 5555'. Make connection & wash down to 5645' (137' above top perf) @ 6.5bpm, 1500psi. No pressure increase seen. Circ 1.5x btms up - returned cmt contaminated mud (dumped 80bbls). Pull out 1 std and wash across ZXP & i liner top f/ 5510' f/ 5470' for 15 min @ 6.5bpm, 1500psi. Mixing dry job. 1 11/29/2007 21 :30 2.50 11/30/2007 00:00 Trip Out of Hole 15 )Pump at* & POOH f/ 5470'. Out of hole & 5/O stinger c111 EOT. 11/30/2007 00:00 1.50 11/30/2007 01:30 Rig - Service 5 Service rig change out swivel packing 11/30/2007 01:30 ( 4.00111/30/2007 05:30 Tripping In 15 Caliper bit sub and scrapper pick up same trip in hole to 5,450' 11/30/2007 05:30 2.50111/30/2007 08:00 ! Rig - Repair 5 i Swivel packing still leaking repack washpipe. 11/30/2007 08:00 2.00 11/30/200710:00 Circulate & Condition 5 circulate down to liner too it 5.472' circulate bottoms uD a 8 BPM 1650P$1 move drilpipe in derrick and 31/8" drill collar so it was accessible for trip in 11/30/2007 10:00 3.00 11/30/2007 13:00 Trip Out of Hole 15 Pump dry job and POOH. 11/30/200713 :00 1.50 11/30/2007 14:30 BHA - PU/MU*" 5 Make up Bit and bit sub pick up 9 doll collars off walk run 1 stand out of 1 Iderridc 1 11/30/2007 14:30 3.00 11/30/2007 17:30 Tripping In 5 )RIH & tag cmt (rD 5677'. P/U =135, S/0 =112k. 11/30/2007 17:30 ' 2.50 11/30/2007 20:00 Drilling - Rotary (No 15 Kelly up & begin ddgx nt. 4-6k WOB, 40rpm, 3.5- 4ktorq. 40spm © 925psi. Motor) i Driq hard & soft ant to 5793' - hard and below tarts. Soft ant only in returns. 11/30/2007 20:00 1.00 11/30/2007 21:00 Circulate & Condition 15 CBU for pert test. ! 11/30/2007 21 :00 1.50 11/30/2007 22 :30 Casing - Pressure 5 R/U test chart on manifold & close pipe rams for pert test U 125Opsi w/ 9.5ppg Testing mud. First test leaking off tl pumps. Bleed off, swap test chart t/ choke manifold & fill same. Pum t/ 1250 ' & strain. Close )BOP & double block valves - good test (50pst rop n mm . 11/30/2007 22:30 1.50 12/1/2007 00:00 Drilling - Rotary (No 5 1Cont dog cmt & washing down to 5860' @ EOT. 4 -6k WOB, 4orpm @ 3.5k Motor) Itorq.45spm @ 1000psi. Intermittent hard & soft cmt dog - continuous cmt contaminated mud back. 12/1/2007 00 :00 1.00 12/1/2007 01 :00 Drilling - Rotary (No 5 Drig ant U 5857' U 5865'. 6k WOB, 45rpm w/ 4k torq. 4.2bpm 0 1000psi. Motor I 1 5 01:00 0.50.12/1/2007 01:30 Rig - Service 5 Make connection & swivel leaking. Rack back & check - loose. Tighten & test. 12/1/2007 01:30 1 6.50112/1/2007 08:00 Drilling - Rotary (No 5 Drighwashing art U 5865' d 6127'. TT solid cmt 6127'. 6k max WOB, Motor) 1 45rpm w/ 4-4.5k torq. 4.2bpm @ 1uuupst. cm op retainer @ 6220'. 12/1/2007 08:00 6.00 14:00 Drilling - Rotary (No 5 Begin drlg upper plug w/ 6k WOB, 45rpm, 42spm @ 1000psi. Slow progress - Motor) I torq jumping from 3.5 to 5k while drag. 12/1/2007 14:00 3.50 12/1/2007 17:30 Drilling - Rotary (No 5 Break thru plug & dna hard ant fl 6223' t/ 6245' (5' below lower pads). Torq Motor) [jumping f/ 3.5k t/ 5.5k. 6k WOB, 42spm O.' T608psi• 112/1/200717:30 0.50;12/1/2007 18:00 Circulate & Condition 5 CBU f/ lower perf test - cmt returns throughout. 1211/2007 18:00 1.00 12/1/2007 19 :00 Casing - Pressure 15 Pull one stand above parts. R/U test pump on pipe. Bring up pressure U Testing 1 500psi w/ rig pumps. Swap to test pump. Pressure up to 95Opsi & broke back to 750psi - appear to be injecting .25bpm C` 750psi• Shutdown & swap to rig '.. pumps. Pressure up to 1250 & shut! n - drop to 550psi & holding. Pressure up t/ 1250 & drop to 550psi. R/D test equipment & kelly up. 12/1/200719:00 0.50 12/1/200719:30 Circulate & Condition 1 5 Break circ while mixing dry job. Pump slug f/ TOOH. 12/1/200719 :30 3.50 12/1/200723:00 Trio Out of Hole 5 POOH racking back 31/8' collars. Break of f bit & bit sub - 2 chipped teeth, 75% bearing life left. 7 23:00 1.00 12 2/2007 00:00 Tripping In '.5 I M/U 2 7/8' mule shoe & XO. RIH w/ 5 stds 2 7/8" DP EOT. 12/1/200 2300 00 / @ ! 12/2/2007 00:00 3.00 12/2/2007 03:00 Tripping In 5 (P/U 2 7/8" tubing muteshoe 1,135' 2 7/8 tailpipe RIH to 6,245'. P/U =145k, 1S/0 =112k. ! 112/2/2007 03:00 1.50112/2/2007 04:30 Circulate & Condition ! 5 Circulate hole clean & mix cement. Accidently pumped water into bulk cement silo. Max cement density was 15.3ppg. 1 12/2/2007 04:30 1.00 12/2/2007 05 :30 Cement - Squeeze 15 Pressure test line to 4,000 PSI pump 2.8 BBLs Chemical wash, 8 BBLs Pert 1 . cement and duck wail ,ift BKt,,+i mtal 12/2/2007 05:30 0.50 12/2/2007 06:00 Trip Out of Hole 15 Pull 6 stands to 5,680'. , 12/2/2007 06:00 1.00 12/2/2007 07:00 !Circulate & Condition 5 (Circulate bottoms up -- 6 BPM 1,200 PSI. Dumped 49 BBLs contaminated !mud, never saw any pure cement I 12/2/2007 07:00 2.00' 09:00 ! Cement - Squeeze 5 Hesitate squeeze I Perf 1 Pumped 1.8 bbls pressure up to 900 PSI bled off to 750 PSI in 30 Min. I Pumped .4 bbls pressure up to 1,100 PSI bled off to 900 PSI in 30 Min. Pumped .4 bbls pressure up to 1,250 PSI bled off to 1,100 PSI in 30 Min. 12/2/2007 09 :00 7.00 12/2/2007 16:00 Cement - Squeeze 5 1 Pump up to 1,250 PSI bled off to 950 PSI in 7 Hrs. I Pert 12/2/200716:00 0.50 12/2/2007 16:30 I Circulate & Condition 5 Pump dry job and blow down lines. 12/2/2007 16:30 2.00112/2/2007 18:30 (Trip Out of Hole 15 (Trip out of hole t/ 2 7/8" DP. 12/2/2007 18:30 1.00112/2/2007 19:30 Trip Out of Hole 5 Cont POOH w/ 2 7/8" DP & rack back. 12/2/200719:30 2.50 12/2/2007 22:00 (Tripping In 5 1 M/U 4 1/8" bit w/ XO. RIH w/ 123 1/8" DC and 20stds 2 7/8" DP for cleanout. 12/2/2007 22:00 1.50 23:30 Tripping In 5 RIH w/ 3 1/2" DP t/ 5672'. P/U =130, S /0 =110k. III III Chevron Chevron - Alaska Time Log Summary Sort Well Name Feld Name API /UWI Lease /Serial CHEVNO License No. /Prope... Ong KB Elev (ft... Water Depth (ft) M -17 McArthur River Field '.507332055200 ADL017594; '� _', 2071200 '._ 79.2 185.00 - -- Start Date - - Our (hie) End Date Activity i Bit/Gag Si - - - _ Comment. 12/2/2007 23:30 0.50 12/3/2007 00:00 Wash & Ream 5 Wash f/ 5672' U @ 5948 4bpm, m, 950 si with no sign n of cmt. 12/3/2007 00:00 1.00112/3/2007 01:00 (Tripping In 1 5 (RIH washing down @ 4bpm, 1000psift 5948' U 6198' - tag cement @ 6198'.; 12/3/2007 01:00 0.50'12/3/2007 01:30 Drilling - Rotary (No 5 Begin drig cmt f/ 6198' U 6227' - not taking any weight when rotating. Ok WOB, 1 Motor) 40rpm w/ 4500 torq, 4bpm @ 1000psi. 12/3/2007 01:30 1.00 12/3/2007 02:30 Circulate & Condition 1 15 i CBU U check cmt returns - all green cmt. 12/3/2007 02:30 6.50112/3/2007 1 09:00 Cement - Waiting "" 5 Pull 1 std & circ slow while WOC. 12/3/2007 09:00 0.50112/3/2007 09 :30 Testing I - Pressure t© 5 Retest upper perfs 5782 -86' t/ 1250psi good: g 12/3/2007 09:30 0.50 12/3/2007 10:00 Drilling - Rotary (No 5 Ddg cmt f/ 6227' U 6245 with no WOB. Motor) 12/3/2007 10:00 0.50112/3/200710 :30 (Circulate & Condition ! 5 1CBU to check ant - green cmt returns. 12/3/2007 10:30 2.50 12/3/2007 13:00 Casing - Pressure 5 Test lower oerfs (61 6234 -40' U 1250psi - 100psi bleed off in 30min. Blow down Testing TD & R/U test pump for second test. Pressure up to 1250ps1- dropped to 1100psi. No test. 12/3/2007 13:00 0.50 12/3/200713:30 Dating - Rotary (No 15 Finish drig Out cmt t/ Motor) 12/3/2007 13:30 1.00 12/3/2007 14:30 Circulate & Condition 5 CBU & mix dry job. Pump slug for TOOH. 12/3/200714:30 4.00112/3/200718:30 4Trp Out of Hole 15 POOH racking back 2 7/8" DP & 3 1/8" DC. Break off bit & bit sub: 12/3/2007 18:30 4.50 12/3/2007 23:00 Tripping In 5 M/U 4 1/8" bit, csg scraper & bit sub. RIH w/ 4 stds 3 1/8" DC & 6 stds 2 7/8" I DP. Cont RIH on 3 1/2" DP washing f/ 6035' U 6230' - no tight spots seen. 12/3/2007 23:00 1.00 12/4/200700:00 Circulate & Condition 5 Begin ckc btms up. Pull one std & cont CBU washing across 6210' for new retainer. 12/4/2007 00:00 0.50 12/4/2007 00:30 I Circulate & Condition I 1 Finish CBU - no cmt back to surf. Pump slug. 12/4/2007 00 :30 2.50 12/4/2007 03 :00 Trip Out of Hole 5 POOH w/ 31/2" DP & rack back 6 stds 2 7/8" tbg - no overpuR seen on TOOH. 12/4/2007 03:00 1.00 12/4/2007 04:00 BHA - PU /MU"" '5 UD 12 3 1/8" DC. B/O bit, scraper & bit sub. 12/4/2007 04 :00 E 1.00112/4/2007 05 :00 (BHA - PU/MU'" 15 1P/U. 5" EZSV & setting tool. 12/4/2007 05:00 4.50 12/4/2007 09:30 ,Tripping In 5 RIH w/ 9 stds 2 7/8" DP & 3 1/2" DP U 6209'. Watch drag & overpull thru 5" 1 liner. P /U =150k, S /0 =120k. 12/4/2007 09 :30 1.00 12/4/2007 10:30 1Crrcutate & Condition 15 (CBU Ci 4bpm,1050psi• 12/4/2007 10:30 0.50112/4/2007 11:00 Cement - Set 5 Locate HES EZSV @ 6209' & attempt to set same as per HES procedure - 'Retainer turned drill string 35 turns to the right & picked up, did not observe any over pull or shear out - Stroked DP up 20' & back down 15' no set down observed - repeated setting procedure - no clear confirmation of EZSV being set. - Informed office of situation & decision was made to POOH & check setting tool. 12/4/2007 11:00 1.00 12/4/200712 :00 Trip Out of Hole 5 POOH U check retainer & setting tool f/ 6209' U 5407'. No overpull seen thru I 1 5° liner. P/U= 135k „S/0 =110k. { 1 12/4/2007 12:00 0.50 12/4/2007 12:30 Circulate & Condition 5 Break circ U pump slug - suction line to charge pumps plugged. 1 12/4/2007 12:30 2.00 12/4/2007 14:30 Rig - Repair 5 II Circ on hole. Troubleshoot charge pumps suction lines. Swapping fluid in pits f& build slug. 12/4/2007 14:30 0.50 12/4/2007 15:00 Circulate & Condition 5 Pump slug f/ TOOH. 12/4/2007 15:00 3.00 12/4/2007 18:00 Trip Out of Hole j 5 Finish POOH ff 540T. Retainer not on setting tool. Tool fully extended - 11 appears to have set downhole. 12/4/2007 18:00 3.50 12/4/2007 21:30 Tripping In 5 RIH w/ setting tool U find top of retainer. 12/4/2007 21:30 1.00 12/4/2007 22:30 Circulate Condition 5 (Ci above the EZSV prior to sting in & establish in) pressures. 12/4/2007 22:30 1.50,12/5/2007 00:00 Casing - Pressure & 5 Sting into EZSV @ 6207' W/ 15k dn - Pressure up below EZSV to 2000 psi 111 Testing atter pumping 9/ 1 of a bbl Pressures were as follows, after 1/10 bbl pumped 300 psi, 1/8 - 600 psi, 2/5 1000 psi, 7/10 - 1500 psi, 9/10 - 2000 psi - pressure after 5 min = 2000 psi - Unstung from EZSV stroked DP and stung back in - Results of second inj test same as first - Unstung, stroked pipe & set dn 35K on EZSV - Pressured to 2000 psi W/ 9/10 bbl, recorded on chart, 30 (min - Good test. Test above EZSV to SFC. with 1[bU psi on chart su mm - 1 , good test I I I 12/5/2007 00:00 2.00 12/5/2007 02 :00 Casin g - Pressure 5 Unsling fl retainer @ 6207' & <�e pipe rams. Retest upper perfs @ 5782-81f fp9 Testing U 1250ps1- good. . 12/5/2007 02:00 1.00' 12/5/2007 03:00 Casing - Pressure 5 Sting back into retainer & test lower perfs U 2000psi - good. Testing I 1 1215/2007 03 :00 4.00112/5/2007 07 :00 Trip Out of Hole 15 !POOH w/ stinger f/ 6207'. P/U =150k, SIO =115k. ■ 12/5/2007 07:00 1.50 12/5/2007 08:30 BHA - PU /MU ** '5 P/U 12 3 1/8" DC & M/U 4 1/8" bit & bit sub. 12/5/2007 08:30 2.50 12/5/2007 11 :00 Tripping In 5 RN w/ 12 DC, 20stds 2 7/8" DP & 31/2" DP. Wash to lop of retainer @ 6207'. P/U =150k, 5/0 =115k. 1 12/5/2007 11:00 ! 0.50 12/5/2007 11:30 Drilling - Rotary (No 5 Begin drilling on retainer @ 6207'. 6k WOB, 45rpm w/ 4 -5k torq, 40spm @ II Motor) 1300psi. I II 12/5/200711:30 1 0.50112/5/200712 :00 Safety 5 Fire alarm in mud pump room. Shutdown & shutin - muster in break room. Meetings/Drills Alarm checked by production all dear. 12/5/2007 12:00 1.50112/5/2007 13:30 Drilling - Rotary (No !, 5 Cont drig on retainer. Break thru after making 1' - packer fell to top of perfs. Motor) I 12/5/2007 13:30 I 2.00 12/5/200715:30 Drilling - Rotary (No 5 Chase packer thru perfs f/ 6234' U 6253'. 6k WOB, 40rpm w/ 5k torq, 40spm 1 Motor) @ 1250psi. 12/5/2007 15:30 1.00 12/5/2007 16:30 I Circulate & Condition 5 1 CBU @ 4.5bpm, 1450psi - small amount of rubber while circulating. 12/5/2007 16:30 j 1.50 12/5/2007 18:00 Casing - Pressure 5 Pull one stand, M/U TIW & fig choke. Close pipe rams & attemptto test both Testing pert sectional/ 1250psi. Working valves & checking leaks. Double block all ` lines after pressuring up U 1250psi - 50psi drop in 30 min. 12/5/2007 18:00 1.50 1 '12/5/2007 1 9:30 Drilling - Rotary (No 5 Cont drig on EZSV, CIBP & CMT F/ 6253' T/ 6266' W/ 5k - 8k WOB, 4 BPM - Motor) (1100 psi - 5K - 7K torque. 12/5/2007 19:30 4.50 12/6/2007 00:00 [Wash & Ream 5 Wash & Ream down F/ 8266' T/ 7435' - Pumping � 4 bpm - 1100 psi, f 1 Rotating @ 50 RPM - 5k - 6k of torque - P/U = 160K S/O = 122K 12/6/2007 00:00 0.50 12/6/2007 00:30 Tripping In 5 Cont washing down 5" liner U top of landing collar. 4bpm @ 1300psi. P/U =160, S/0 =125k. Tag @ 7546'. 12/6/2007 00:30 I 1.50112/6/2007 02 :00 Circulate & Condition 15 Cont circ & pump hi visc sweep. CBU % 8bpm, 2600psi. Mix and pump dry Job. 12/6/2007 02:00 4.50 12/6/2007 06:30 Trip Out of Hole 5 POOH f/ 7546'. P /U =180k, S /0 =130k. • 0 Chevron Chevron - Alaska Time Log Summary Sort Well Name Field Name API /DWI Lease /Serial CHEVNO License No . /Props...', Orig KB Elev (ft... ', Water Depth (ft) M -17 McArthur River Field 507332055200 ADL017594; LB2629 X 2071200 79.2 185.00 , best Oslo i Our dind End Dale - F __ Activity g '/Gse Sz - Comment 12/6/2007 06 :30 4.00 10:30 Tripping In 5 M/U 5" csg scraper & RIH 23 stds 2 7/8" DP. Cont RIH w/ 3 1/2" DP thru 5" liner. No tight spots seen. Tag @ 7546' & rack back stand. 12/6/2007 10:30 2.50 12/6/2007 13:00 (Circulate & Condition I5 'P/U 30' and sire 1.5x bottoms up. Pump 40bbl hi visc sweep & displace w/ FIW. Pump sweep out of bow & coot kirk w/ FIW until clean - 450th total 12/6/2007 13:00 2.50 12/6/2007 15:30 Trip Out of Hole 5 I POOH w/ 3 1/2" DP racking back. 12/6/200715:30 1 4.50 20:00 1Trip Out of Hole '5 IUD 2 7/8" DP & 31/8" DC. 12/6/2007 20:00 4.00 ,12/7/2007 00:00 Tripping In 5 P/U & M/U Baker Polish Mill & TIH T/ 5470 Acquire P/U - 148K, S/O - 112K. ROT - 130K, Torque - 5K & Pump Pressure values - S/O pumping @ 4 bpm / 300 psi, rotating @ 45 RPM - No -Go @ 5483' - Did not observe indication of entering PBR - Worked PBR mill in & out 2 times, P/U to 10' above PBR & start to CBU @ 8.5 BPM. 1277/2007 00:00 1.50 12/7/2007 01:30 I Circulate & Condition 15 I CBU @ 8.5bpm, 1800psi, Flush choke lines. :12/7/2007 01:30 7.00112/7/2007 08:30 ,Trip Out of Hole 5 POOH laying down 3 1/2" DP. 12/7/2007 08:30 1.50 12/7/2007 10 :00 f Rig Up / Rig Down "` 5 :Pull wearbushing. R/D elevators & dear floor. lJD all unnecessary tools & equipment. 12/7/2007 10:00 0.50 12/7/2007 10:30 Rig Up / Rig Down*' 5 R/U tbg tongs & equipment. 12/7/2007 10:30 1.00112/7/200711 :30 Tubing - Running 15 IP/U seal assembly, 1 it 3 1/2" tba. X nipple, 1 It 3 172" tbo & GLM #1. 1 ! 12/7/2007 11:30 12.50 12/8/2007 00:00 ,Tubing - Running 5 RIH W/ 3 1/2" production tbq as per procedure - refer to tbg detail for running , order & setting depths. 12/8/2007 00:00 2.00 12/8/2007 02 :00 :Tubing - Running 15 Cont RIH w/ 31/2" tbg, R/U circ & pump slow into seal assembly @ 5470' ' (tubing tally depth). PIU =115, S/O =95k. 1 12/8/2007 02:00 1.00 12/8/2007 03:00 Test - Tubing 5 I Set down on seal assembly w/ 10k & R/U pressure equipment. Test tbg to 1000osi for 30 min - good.. i 12/8/2007 03:00 1.00 12/8/2007 04:00 Tubing - Running 15 Pill & collect spaceout measurements for landing hanger. P/U 2 pups and run in string. 12/8/2007 04:00 2.00 12/8/2007 06:00 Circulate & Condition 15 Break circ & prep packer fluid. Begin displace 7" x 3 1/2" annulus w/ 6% KCI w/ Baracor - chase down tbg w/ FIW. 12/8/2007 06:00 1 2.00112/872007 08 :00 Tubing - Running 5 M/U hanger & run control line thru hanger. Pressure test line V 5000psi - 12/8/2007 08:00 3.0012/8/2007 11:00 Test - Tubing 5 Space out & land tba hanger W/ 14k on no go - R/U circ hose & head pin. Run in lock down screws. Pressure test tbg V 1000psi for 30min - good. R/D chart recorder & circ equip. ,12/87200711:00 2.00'12/8/2007 13:00 Rig Up / Rig Down" 5 LJD landing it & set BPV - R/D Weatherford equipment & clear rig flow of excess equipment. t 12/8/2007 13:00 1.00 12/8/2007 14:00 Rig Up / Rig Down*" 5 Prepard deck - Remove beaver slide & cat walk. 12/8/2007 14:00 I 2.00112/812007 16:00 f Rig Up / Rig Down"' 5 1 Remove thwarter assy from cellar. 12/8/2007 16:00 3.50 12/8/200719:30 BOP - Nipple Down 15 R/D Flowline & turnbuckles R/U tiggers & remove lower bop rams. : ! 12/8/200719:30 0 -50 12/8/2007 20:00 Safety 5 Report to muster for gas alarm. (False alarm in cement room) Meetings/Drills j 12/8/2007 20:00 4.0012/9/2007 00:00 Rig Up / Rig Down" 5 I Build & inspect scaffolding as required - Flush trip tank & pumps with fresh ! water - Flush & drain csg fill up line, 2- degasser pumps, flow trough & dump, desander & desilter, 2 charge pumps, 2 mix pumps, hopper lines, 2 mud I pumps & pop off for same, all mud lines, pit suctions, gun lines & mud cleaner 1 1- Clean and wash out pits - Continue with N/D operations - Crane crew 1 backloaded boat W/ Schlumberger equipment, rental DP & other equipment. I I Daily cost is elevated due to adjustments for: Wellhead, Liner Hanger, Liner, 1 Cement Work, and misc other expenses. , 12/9/2007 00 :00 9.00 12/9/2007 09:00 BOP - Nipple Down 5 Continue to N/D BOP'S - Remove upper & blind rams, clean & lubricate ram cavities, seals, etc - Remove flow nipple, Choke & Kill fines & disconnect koomy hoses from upper well bay, wrap & store same in cellar. - Lift BOP'S & set back on stump, secure same - NID & remove riser sections. I 12/9/200709:00 4.00 12/9/2007 13:00 Wellhead - Nipple Up 5 I Remove wing valve & actuator from production tree to allow passage through 1 1 ,,,/ hatch in wellhead room - Installed production tree. 1219/2007 13:00 1.00 12/9/2007 14:00 Wellhead - Test 5 `Tested production tree voids & neck seals to 250 psi low - 5000 psi high for / 130 min ea (All good tests) 12/9/2007 14:00 1 0.50112/9/2007 14:30 Wellhead - Nipple Up 5 I Install actuator & wing valve back on production tree. 12/9/2007 14:30 1.50112/9/2007 16:00 Wellhead - Test 5 Pulled SPY & installed TWC - Tested production tree (body test) to 250psi low & 5000psi high for 30 mkt each (good test) - Pull TWC. 12/9/2007 16:00 2.00112/9/2007 18:00 Rig - Cut & Slip Drill 5 Cut & Slip 106' of Drill Line. ! Line 12/9/200718:00 6.00 12/10/2007 00:00 DeMob" 15 Start to dean rig - R/D derrick equipment, - Fill choke manifold with oil & i service valves on same - Pick up & put away tools - Service crown. 112/10/2007 00:00 6.00112/10/2007 06:00 i DeMob" ', 5 !While Cleaning rig top - Removed stabbing board winch, Serviced op drive & drawworks - Cleaned out dry sack room. Continue to address demob list. 12/10/2007 06:00 6.00 12/10/2007 12:00 DeMob'" 15 Cleaning in rig subbase - Store all BOP rams & 16-3/4 gray lock clamp in S.E. Upper Wellhead Room, cleaned & organized same - Continue W/ demob 1 list 12/10/2007 12:00 6.00 , 112/10/2007 18:00 DeMob" 15 R/D high pressure mud hose & choke panel - Drain low pressure mud hose, I I sea water hose & deluge system, coil hoses in in well bay - Secure diverter lines - Continue with demob list. ■ 12/10/2007 18:00 6.00112/11/2007 00:00 :DeMob ** 15 Continue to RID deluge system - Clean well bay - Remove stand pipe I manifold front rig floor & prepare to send same to Peak - Bleed down steam system - Start to drain glycol system - Clean skid beams in preparation for rig skid - working on storm clamp removal. I 12/11/2007 00:00 10.00 10:00 I Rig Up / Rig Down" 5 Rig down remaining service lines and store in cellar Prepare to skid rig remove back stairs from rig remove storm clamps and install rail guides 12/11/2007 10:00 14.00112/12/2007 00:00 1Rig Up / Rig Down" 5 1 Jack rig to center postion install storm damps • • Chevron Chevron - Alaska kilil Time Log Summary Sort I Well M -17 me McArthur River Field 507332055200 'ADL0 LB 629 207 200 Orig KB 79.2 (e , Water (ft) 'Flee Name API/LIWI 185 00 startDete 1 Dur End Dare 7 Activity BNCSB§z F - - -. -- - -.. -- - Comment 12/12/2007 00:00 8.50 12/12/2007 08:30 Rig Up / Rig Down** '5 Install lower storm clamps,drain oil from choke manifold,rig up air to rig ,secure diverter mud cross in sub base,claen up mud from SW hatch area,rig up Mag -tec heaters and get heat into sub base,install barriers around SW hatches,remove hatches, remove high pressure mud hoses from upper well room, over board lines and drain lines, cover drawworks W /tarp, work on agitator in pit #4. 12/12/2007 08 :30 i 1.00;12/12/2007 09 :30 Safety 5 Held safety shut down to discuss incident in upper well room Meetings/Drills j 12/12/2007 09:30 ', 9.00,12/12/2007 18:30 Rig Up / Rig Down** !, 5 :Continue working on agitator in pit #4,organize doghouse,claen out shelves and tool box in doghouse lockout pumps with production,finish rigging up air to rig floor,bring 110V to rig floor,rig up pit dump in cellar 12/12/200718:30 2.00 12/12/2007 20:30 lSafety 5 Went over cause and effect of incident in upper well room W/ drilling manager 1Meetings/Drills, and drilling superintendent 12/12/2007 20:30 3.50 12/13/2007 00:00 Rig Up / Rig Down" 5 Unload boat and backload same,clean discharge and suction screens on mud !, pumps,PPE inventory on rig floor, clean drilling conex 12/13/2007 00:00 1,50 12/13/2007 01:30 1Safety 1 5 Safety Stand down with NAD morning tour drilling crew discussed safety 1 Meebrtgs/Drlls attitudes,went over cause and effect off incident 12/13/2007 01:30 ! 16.00.12/13/2007 17:30 Rig Up / Rig Down** 5 Install hatch covers for night,install new lines on manrider,new line on driller ! side air hoist clean and organize pump room,remove center hatch onSW ! upper well room install wireline hatch,build railing around open section of I hatch,install spool on Schlumberger unit, change out spider in #3 cement ,tank. 12/13/2007 17:30 6.50 12/14/200700:00 Safety 5 Start shuttling all drilling personal to beach. Run SCMTT.Stopped @2,450" Meetings/Drills worked to 2,500 stopped again POOH,Pick up 1 11116" 011 weight bar and 2 1/2" OD,CCL ! 12/14/2007 00:00 6.00112/14/2007 06:00 Log - Cased hole 5 Finish POOH with Cement bond log. Rig down SLB tools & equipment. Remove wireline access platform & install deck hatch covers. Secure area & prepare for transport to IFO stand down. . 5 Rig `seared & shut down. Employees 12/14/2007 06:00 18.00 12/15/2007:0000 Safety pWyees flown in for a lEO stand down meeting. Meetings/Drills Al employees returned & back on rig n _ 2000 hrs. ! 12115/2007 00:00 5.00 12/15/2007 05:00 Safety 1 5 Crews off until 0430 held PJSM i Meetings /Drills 12/15/2007 05:00 19.00112/16/2007 00:00 DeMob'* 15 Clean cement room remove 3 drums cement waste,clean and grease ring I grooves on mud cross,string up off driller side tugger inspect swivel on line change out same,dril out alien screw in tugger drum and tap same,remove bales from blocks,dean and organize shelves in cellar,130P landing and shaker room. Organize flamable liquid lockers on rig floor,remove overboard lines off pits and blind flange same.String up new on driller side Itugger.remove bales and wire from rig 1bor .Cleaning drilling conex 1 tanks and mix room or ante and sort out cellar 4. 12 17/2007 00:00 'DeMOb" ' S Clean behind bulk cement a 12/16/2007 00:00 2 00 / 9 , ! iarea,restack koomey lines,rig down fill up line,possum belly. Clean dry sack , , room sort trash and remove same,Hook -up Gai- tronics to rig floorhang 'laminated signs on weight indicator for brake cooling and traction motor wamings,clean pump room, inventory pump parts.Cover drawworks blowers.Build scaffoOlding hand rails around hatch area,stoer catwalk and : beaverslide on top of quarters,remove hatchcovers on upper well room pull !risers install chemical tote.Place two hatch covers over upper well room lower j , basket fill basket with junk rollers install third hatch piece, Fill heaters 12/1712007 00:00 17.00 12/17/2007 17:00 Debtor)** , 5 `Continue to clean up upper well room,chipcement off wals of cement room ! ,haul off drum of cement ,unplug and redress gun line.toad up junk out of well ! I :room string hose from choke manifold to side of building 12/17/2007 17:00 7.00112/18/2007 00:00 Rig Up / Rig Down** 5 !Unload coil tubing off boat,back load boat for Anna and beach, line up coil pieces,continue cleaning 12/18/2007 00:00 5.50 12/18/2007 05:30 (DeMob" 5 Inventory and replace parts in Cortex's rig up fuel hose from south crane.prepare back load 12/18/2007 05:30 0.50 12/18/2007 06:00 'Safety 5 PTSM W/ Schlumberger and NAD crew,McKinley crane crew went over coiled Meetings/Drills tubing rig -up 12/18/2007 06:00 16.00 12/18/2007 22:00 Rig Up / Rig Down" 5 Ri to ' .unload boat with last of coil equlpment,back toad boat, -up hard line to pumps rig-up BOPE on well head,Hook centifugal for mixing KCL 12/18/2007 22:00 2.00112/19/2007 00:00 DeMob" 5 Clean out cabinets for pump parts inventory and sort parts in storage cabinets 12/19/2007 00:00 I 5.50112/19/2007 05:30 Rig Up / Rig Down" 5 Rig up choke manifold to take nitrogen returns to gas buster, insurer doors ■ V -doors on rig floor were latched down and secure,rig` up to take glycol back ■ Ito barrels 12/19/2007 05:30 8.00 12/19/2007 13:30 BOP - Nipple Up 5 !Run hard lines and finish nipple up BOPE ! 12/19/2007 13:30 ( 2.00 12/19/200715:30 BOP Test 5 Test BO PE to 250 PSI low 3:00Q PSI high test slips, rams, blind rams, shear rams and 14 valves on hardlines ,12/19/2007 15:30 2.50 12/19/2007 18:00 Rig Up / Rig Down** 5 Pick up injector head and stab onto well 12/19/2007 18:00 6.00112/20/2007 00:00 Rig Up / Rig Down 5 Unload boat Test lubricator 250 PSI low 3,000 PSI high drain glycol fromlubricator and suface lines and shutdown twice tubing for night 12/20/2007 00:00 2.00112/20/2007 02:00 , Rig Up / Rig Down** 5 Drain glycol back to BBLs, blow down hardlines and choke ' 1 112/20/2007 02 :00 ! 5.50 12/20/2007 07 :30 [Rig Up / Rig Down" 5 'Fuel heaters, store parts in mud boxes,Clean out doghouse, Work an chart L 1 I recorder, rig up blow down line for KCL supply line • • Chevron Chevron - Alaska Time Log Summary Sort Well Name License No. /P ',Field Name API /UWI 'Lease /Serial CHEVNO License Ong KB Elev (ft. Water Depth (ft) M -17 McArthur River Field 507332055200 ADL017594; LB2629 2071200 79.2 185.00 Start bete ,our Ors) j . Ertl Dale 1 - - - --- AouVttg aitlCSg SZ - -_ - -- - -- . Comment 12/20/2007 07:30 10.50 ,12/20/2007 18:00 Coil Tubing - 5 Start-up engines prep nitrogen RIH with coil tag @7,525' P/U to7,519' Washing displace fluid out of well bore recover 38.3 BBLs Max. surface pressure 2,535 PSI, Bled nitrogen off held 600 PSI on back side untill it came down on its own opened wide open @ 150 PSI. Drain gas buster, ship 12 BBLs KCL pill to Coil unit pump same whilst POOH 6 BBLs back chlorides 14,000 18 BBLs back chlorides 14,000 25 BBLs back chlorides 21,000 38 BBLs back chlorides 25,000 FIW chlorides 14,000 6% KCL pill chlorides 27,500 12/20/2007 18:00 2.00112/20/2007 20 :00 ; Rig Up / Rig Down 5 Pick off injector head, break down circulating nozzle set injector head aside and chain to deck 12/20/2007 20:00 4.00 00:00 Rig Up / Rig Down" 5 Break off coil lubricator above rams, rig up wireline pick up lubricator stab on 1 and test to 3,000 PSI drain lines and RIH W/perf guns 1 12/21/2007 00:00 1.50112/21/2007 01 :30 1 BOPTest 15 Testing Wireline BOPe froze up lubricator thaw out and test 40250 PSI tow 1 3,000PSI high 12/21/2007 01:30 2.50 12/21/2007 04:00 Log - Cased hole 5 IRIH to 7,456' top of guns tied in W /SCMT of n' . 11/22/0/ Fired guns @0240hrs pressure came up from 700 PSI 1,100 PSI 4 Min 1,300 PSI 8 Min 1,500 PSI 15 Min 1,650 PSI 20 Min 1,710 PSI 38 Min 1,825 12/21 /2007 04:00 5.50112/21/2007 09:30 'Monitor 5 Monitor well and wait on orders 1 12/21/2007 09:30 6.50 12/21/2007 16:00 Rig Up / Rig Down** 15 Sent 1 rig crew to Anna , Rig down coiled tubing and wireline 12/21/2007 16:00 G 2.00112/21/200718:00 (Standby 5 Wait on boat 12/21/2007 18:00 5.00112/21/2007 23:00 1 Rig Up / Rig Down" 5 Back load coiled tubing unit on boat release Schlumberger Coil personel and 11 Schlumberger wireline personel 12/21/2007 23:00 1.00 12/22/2007 00 :00 DeMob'" 5 I Send all Schlumberger crews to town ! 12/22/2007 00:00 1 9.00112/22/2007 09:00 DeMob" 5 Finish pickling pumps Rearange deck to rig -up for wireline 12/2212007 09:00 1 3.00112/22/200712 :00 'DeMob" 15 ,Start ferring people to Dolly Varden/Monopod/ Release Nabors 1200 Hrs. 12/26/2007 00:00 14.00,12/26/2007 14:00 Inactive" 5 12/26/2007 14 :00 1.50 12/26/2007 15:30 S afety etirhgs 5 SIMOPS w/ Production and Crane Crew. 12/26/2007 15:30 3.50 19:00 1 Slickline - Rig Up / 5 Mob Equipment to South west deck and rig up. Wait on crane (unloading Test BOPs / Rig boat).MU 2.75 "x 8" GR, 1.75 "x 6' spangs, 1.75 "x 3' jars, 1.75 "x 8" knuckle, 'Down Test 1 11 .75" wt. bar, 1.75 "x 8" knuckle, 1.75 "x 6" rope socket. Presure test 250 psi low and 2500 psi high. Cut O'ring, repair and retest good. 110 psi on tubing, 7 "x 3.5" annulus 100 psi, 9 5/8 "x 7" annulus 120 psi. 12/26/2007 19:00 1.00 12/26/2007 20 :00 Slickline - Gauge 15 IRfH with 2.75 GR tagged fill at 7520' Sliddine, 1540' RKB. POOH Ring 1 12/26/2007 20:00 0.75112/26/2007 20:45 Slickline - Bailing 5 I RIH with 2.5 "x 4' DD Bailer to find fluid level in tubing, Could not identify fluid !level. POOH 12/26/2007 20:45 1.50 12/26/2007 22 :15 Slickline - Rig Up / 5 Rig down Pollard and secure well. Call town, talk to Gary Orr. Make plan Test BOPS / Rig forward. Call Schlumberger for A.M. hellicoptor. Down Test 12/26/2007 22:15 1.751 12/27/2007 00:00 Inactive" 5 1 Plan forward: Schlumberger out in AM to prep well for reperf and reperf D -17 ' sand. 12/27/2007 00:00 6.00112/27/2007 06:00 'Inactive "' 5 I , 12/27/2007 06:00 3.00 12/27/2007 09:00 Safety 5 SIMOPS Move Pollard equipment aside. Pollard rebuilt wireline valves. I Meetings/Drills Schlumberger arrive and new employees orientation. Tubing pressure 140 psi, 7 "x 3.5" annulus 100 psi, 9 5/8 "x 7" annulus 110 psi. 12/27/2007 09:00 4.00 12/27/200713.00 Log Rig Up/ Rig 5 Hold PJSM with crane crew and production. Discuss pumping flammable Down kquids safety y checklist. Review Chevron's 10 tenets of operational excellence 1 and stop work authority. Spot Schlumberger equipment and begin rig up. I Wart on crane, continue rig up. 12/27/2007 13:00 ! 0.50 12/27/2007 13:30 Safety 5 Fire alarm report to muster area. All went well and all personnel reported Drills/Meetings promptly. 12/27/200713:30 2.5012/27/200716:00 Log - 5 MU 1 11/16"x 7.5' Pres/re tool, 1 11 /16"x 12' wt bar, 13/8'k 22" rope Pressure/Telnperat... socket. Check tool string. Stab on well and pressure test. 250 psi low and Survey 2500 psi high. Bleed fluid from lubricator and RIH logging. bated Fluid level at 6810'. Tag fill at 7520'. log short pass and check dated22/Nov/2007. mp Look good POOH. 1 12/27/2007 16:00 1.00 12/27/2007 17:00 ( Preparations" 5 Call Town, E -Mail logs to town discuss next move. Schlumberger on standby. 12/27/2007 17:00 1.50112 /27/200718 :30 Log - Rig Up / Rig 5 Rig down Schlumberger to drill deck night cap lubricator and secure Down equipment for night. Schlumberger off platform at 18:30. 12/27/2007 18:30 2.50 ,12/27/2007 21:00 '1 Monitor Well 5 pro PJSM with production. Presure well to 970 psi with sales gas. Monitor well (steady as a rock) does not seem to be takina any ass at Derts.7 "x 3.5" annulus 100 psi, 9 5/8 "x 7" annulus 110 psi. IFO 12/27/2007 21:00 3.00112/28/2007 00 :00 ,Inactive '"' 5 Plan forward: Get 2,5* spirol EJ gun to platform, Schlumberger to platform I pressure well to 1100 psi (if possible) with gas and raped D -17 sand � 7456'-7470'. 12/28/2007 00:00 6.00 1 12/28/2007 06:00 Inactive" 5 12/28/2007 06:00 1.00 12/28/2007 07:00 ,Safety 15 SIMOPS with production and construction crew and crane crew. Drills /Meetings 12/28/2007 07:00 3.00 12/28/2007 10:00 Monitor Well 5 , Check on well status: Tubing presure 1060 psi, Tx 3.5" annulus 130 psi, 9 5/8 "x 7" annulus 140 psi, 13 3/8 "x 9 5/8" annulus 0 psi, 20 "x 13 3/8" annulus 85 psi. Set up boat with drilling expeditor and schlumberger. Check on hellicoptor, not flying. Schlumberger crew on boat. 12/28/2007 10:00 I 2.001,12/28/200712:00 Inactive'" :5 Wait for boat. _ 1 • • Chevron Chevron - Alaska Time Log Summary Sort 9 rY Well Name - __ -- Field Name ,API /UWI Lease/Senal ' CHEVNO License No./Pmpe...'. Ong KB Elev (ft... ', Water Depth (ft) M -17 McArthur River Field 507332055200 ADL017594; LB2629 2071200 79.2 J 185.00 Stmt Date Trier (hrs)'.._ End Date __.. Activity I BiaCs5Sz, _._ - . -- - -_.. Comment 1 '.. 12/28/2007 12:00 1.50 12/28/2007 13:30 Preparations ** 5 Get hot work permits for SWS equipment. Start equipment and heaters in preperation for boat arrival. Check on well tubing pressure 1070 psi, annulus's no change. 12/28/2007 13:30 ; 1.00!12/28/2007 14:30 1Safety 5 PJSM w/ schlumberger, production and construction foreman. Review Drills/Meetings i 'pumping flammable liquids checklist, Explosive safety cnerklist and wireline ■ operations checklist. Review stop work authority. 12/28/2007 14:30 I 1.50 16:00 Electricline - Rig Up / 5 RU Schlumberger, MU 2.5 "x 14' PowerSpiral EJ 5 SPF, 45 degree phased, 1 Rig Down 11/16 "x 1.5' Safe firing head, 1 11/16 "x 1.5" Magnet, 1 11/16 "x 1' CCL, 1 11/16 "x 1' Swivel, 1 11/16 "x 18' Wt bar, 1 3/8 "x 22" Rope socket. PT lubricator 250 psi low, 3500 psi high. 12/2812007 16:00 i 1.50 12128/2007 17:30 'Perforation - 15 ,RIH, Correlate on depth with schlumberger SCMT log dated 11/22/07. Logged `,Reperforation ;across short joint at 6990' to 7011'. RIH to 7495' log pass to 7280" to confine , I still on depth. Log into position 7456'- 7470, CCL depth 7450' check tubing ■ pressure 1044 psi, contact production, Perforate well Tension dropped 70 '� lbs.Check tubing pressure 1070 psi. Attempt to POOH tool s uck.Presure continue to build slowly to 1130 psi. leveled off for 15 minutes and then I continued to build to 1283 psi with in 1 hr. 12/28/2007 17:30 2.50 12/28/2007 20:00 Perforation - 5 Tool string stuck at 7450' RKB, work cable some movement down then up I Reperforation 10' ) continue to work cable. Call town, Keep working cable. 12/28/2007 20:00 4.00 12/29/2007 00:00 Perforation - 5 Continue to work cable no movement. JSA with production flow well for 25 Reperforation minutes white working cable, Pte luck. Call town work cable to max tension 3600 lbs no luck. Continue to Try to work tension to rope socket. Tubing pressure 1216 psi, 7"x 3.5" annulus 150 psi, 9 5/8"x 7" annulus 140 psi, 13 3/8 "x 95/8" annulus 0 psi, 20"x 133/8" annulus 85 psi. IFO i 12/29/2007 00:00 2.50 12/29/2007 02:30 Perforation - 5 Too of stuck tool at 7436' RKB Bottom of tool at 7476.5', Working cable Reperforation between 2200 lbs tension and 3200 lbs tension. Tubing Pressure 1216 psi, Pull tension on wire to 3000 lbs lock down, set pack offf and monitor. 12/29/2007 02:30 3.50 12/29/2007 06:00 Safety 5 ISIMOPS w/ production, crane crew, construction. 12/29/2007 06:00 6.00112/29/2007 12:00 1Monitor Well 5 1Tubing Presure 1330 psi, 7 "x 3.5" annulus 150 psi, 9 5/8 "x 7" annulus 140 psi, 13 3/8 "x 9 5/8" annulus 0 psi, 20 "x 13 3/8" annulus 85 psi. Tension on wireline 2945 lbs. Call town discuss, Call Schlumberger for T -Bar, and insert's, 1 hand Call pollard check on cutter, they have one. 12/29/2007 12:00 4.00 12/29/2007 16:00 Monitor Well r5 Get plan together, hold safety meetings, generator down (2nd time),Prepare to implement plan. 12/29/2007 16:00 4.00 12/29/2007 20:00 Monitor Well 1 5 Hold tail gate safety meeting. Implement plan to get schlumberger out of well. I Hook to crane and pull to 3500 lbs tool travel, slack back off to 2900 lbs, Bring tension to 3800 lbs tool travel , tension increase to 3900 lbs continue to 1 increase tension to 4000 lbs tension dropped to 1200 lbs. Get off crane. Pull I I Schlumberger wire from well, E -line pulled out of week nnint.Tnnl strinn left in I ' well 2.5 "x 15' gun, 1 11/16 "x 1.5' Safe firing head, 1 11/16 "x 1.5' Magnet, 1 111/16 "x 1' CCL, 1 11/16 "x 1' Swivel, 1 11/16 "x 18' wt bar, 1 3/8 "x 22' Rope 1 socket. w''' j 12/29/2007 20:00 4.00412/3012007 00:00 Electridine - Rig Up / I 5 Rig down schlumberger to drift deck secure well turn well to procducdion. w/ Rig Down Tubing prune 1444 psi, 7"x 3.5" annulus 150 psi, 9 5/8"x 7" annulus 140 psi, 133/8' annulus O psi, 20"x 13 3/8" annulus 85 psi. 12/30/2007 00:00 6.00 12/30/2007 06:00 Inactive** 5 12/30/2007 06:00 I 0.50 12/30/200706:30 Safety 5 SIMOPS, Production, Crane Operator, Construction. O ilts/Meetings Tubing Presure 1390 psi, 7"x 3.5" annulus 150 psi, 9 5/8 "x 7" annulus 140 psi, 1 i 133/8 "x 9 5/8" annulus 0 psi, 20"x 13318" annulus 85 psi. 12/30/2007 06:30 5.50;12/30/200712:00 !, Monitor Well ' �.5 'flowed well, Presure drop to 489 psi and presure lumped up to 1100 psi in 2 � , minutes. contiue to flow well not to exceed 1.5 MCFPII ,. 12130/200712 :00 4.00 1 12/30/2007 16 :00 'Monitor Well 5 - Well flowing better decide to cut Schlumberger loose. Rig down Schlumberger Clean area and button up equipment for move. 1 12/30/2007 16:00 3.00 19:00 Monitor Well 5 Wait for Hellicoptor. Well flowing 1.5 MCFBD at 1370 PSI on tubing. Have 11/ I flowed 23 BW back. 7"x 3.5" annulus 175 psi, 9 5/8 "x 7" annulus 140 psi, 13 3/8 "x 9 5/8" annulus 0 psi, 20'x 13 3/8" annulus 85 psi. 12/30/2007 19:00 I 5.00 412131/2007 00:00 ' � 5 Production to test well . to '1/17/2008 00:00 6.00' 1/17/2008 06:00 Inactive'" 5 , 1/17/2008 06 :00 1.00' 1/17/2008 07:00 Safety i 5 SIMOPS w/ production, construction, crane crews. I I Drills/Meetings 1/17/2008 07:00 2.50 1/17/2008 09:30 Preparations "` 15 Move Hatch cover from NE leg to SW leg. Tubing Presure 1056 psi, 7 "x 3.5" annulus 210 psi, 9 5/8 "x 7" annulus 160 psi, I 1 13 3 /8 "x 95/8" annulus 0 psi, 20 "x 13 3/8" annulus 80 psi. 1/17/2008 09:30 3.00 1/17/2008 12:30 Inactive "" 15 I Wait on crane operator change out. New crane operators inspecting cranes. I 1/17/2008 12:30 3.00 1/17/2008 15:30 Slickline - Rig Up / I 5 Hold PJSM w/ production and pollard. Spot slick line unit and equipment build 1 Test BOPS / Rig new rope socket, , Down Test MU 2.75 "x 10" GR, 1 3/4 "x 6' spangs, 1 3/4 "x 3' jars, 1 3/4 "x 8" knuckle, 1 3/4's 10' stem 1 3/4 "x 8" knuckle, 1 3/4 "x 6" rope socket. Stab well and presure test 250 low and 2500 high. Leak at O'ring. Change O'ring and retest good 1/17/200815:30 1.00 1/17/200816 :30 IStickJine -Gauge 5 4RIH and Tao fish at 7438' RKB POOH Ring 1/17/2008 16:30 7.50 1/18/2008 00:00 Log - 5 MU 1 "x 54" Pres/ Temp tool RIH at 60 ft per min to 7300' w/ tubing presure at 1 Pressure/Temperat... 1056 psi. POOH. Production bleed well to 500 psi and RIH at 60 ft minute to Survey 7300' POOH. 1/18/2008 00 :00 4.00 1/18/2008 04:00 I Slckline - Memory 5 Continue survey w/ 500 psi on tubing. toging Pres( Temp survey at 60' 'Log min.Log to surface close swab bleed lubricator. Download gauges, Secure well and rest.Tubing Presure 507 psi, Tx 3.5" annulus 210 psi, 9 5/8"x 7" I 'annulus 160 psi, 13 3/8"x 9 5/8" annulus 0 psi, 20"x 13 3/8" annulus 80 psi. • • Chevron 1 #100 Chevron - Alaska Time Log Summary Sort Well Name Field Name ',API /UWI LeaselSeriel CHEVNO License No. /Prope...:Ong KB Elev (ft.. Water Depth (ft) M -17 McArthur River Field 507332055200 ADL017594; LB2629 2071200 79.2 185.00 ' "" sum Date our (MS) End Date - - PtgYItY _..: -- :B O° ltlCey. Sal "e "t -- - - - J 1/18/2008 04:00 3.00 1/18/2008 07 :00 Inactive ** 5 1/18/2008 07:00 I 1.50 08:30 Slickline - Rig Up / 5 Rig down and clean up area secure pollard equipment.Tubing Presure 507 Test BOPs / Rig 1 "psi, 7"x 3.5" annulus 210 psi, 9 5/8 "x 7° annulus 160 psi, 13 3/8 "x 9 5/8" Down Test 'annulus 0 psi, 20 "x 13 3/8" annulus 80 psi. 1 1/18/2008 08:30 15.5011/19/2008 00:00 Inactive ** 5 1/24/2008 00:00 7.00 1/24/2008 07:00 Inactive'* 1 5 I Schlumberger Crew at hetiiport 06:00 for 06 :30 flight. Platform at 07 :15. 1/24/2008 07:00 3.00' 1/24/2008 10:00 Preparations*" 5 Hold tailgate safety meeting with Schlumberger and Crane crew. Get hot work permit, schlumberger start equipment and spot equipment to north pipe rack.Build 5x3 weak point (1126 Ibs) Tubing presure 574 psi, 7 "x 3.5" annulus 200 psi, 9 5 /8 "x 7" annulus 160 psi, 13 3/8 "x 9 5/8" annulus 0 psi, 20 "x 13 3/8" annulus 80 psi. 1/24/2008 10:00 1.00 1/24/2008 11:00 'Safety I5 Hold Safety meeting w/ production, Schlumberger and crane crew. Review 'Drills/Meetings f pumping flammable liquids, wire line safety check list, Presure test. 1/24/2008 11:00 4.0011/24/2008 15:00 Electricline - Rig Up / 5 Rig up Schlumberger on well. MU 1 11/16 "x 7.5' possiset plug, 1 11/16 "x 20.5' 1 Rig Down Plug back tool, 1 11/16 "x 18" CCL, 1 3/8 "x 22" rope socket. Schlumberger 1 presure gear hoses froze up, thaw out and Presure test 250 lowand 2500 high. 1/24/200815 :00 3.00 1/24/2008 18:00 "Tubing - Plug Setting "5 RIH to 361' sat down worked wire, no go worked wire by hand suspect wire BP hanging in grease tubes. Suspicions correct POOH cut 400' of wire resbung grease tubes and build new head. Check tool with new head. 1/24/2008 18:00 3.00 1/24/2008 21:00 1 Tubing - Plug Setting 5 RIH with same tool string no problems. Correlate with short joint at 6990'- 1 BP 7010.5' SWS SCMT log dated 11/22/2007, continue in well and tag fill at I 7376' RKB. Log off and try two more times, find fill at 7376' both times. Call town and POOH. 1/24/2008 21:00 1.50 1/24/2008 22:30 Electricline - Rig Up / 1 5 Rig Down Schlumberger and secure welt. Lay down for night. Rig Down Tubing Presure 568 psi, Tx 3.5" annulus 200 psi, 9 5/8 "x 7" anntdus 160 psi, 13 3/8 "x 95/8° annulus 0 psi, 20 "x 13 3/8" annulus 80 psi. 1/24/2008 22:30 1.50 1/25/2008 00:00 Inactive'* 5 Plan forward:Schlumberger to beach,Pollard out to set SSSV's in M -1 and M -5, and run Bailer in M -17. 2/2/2008 05:30 1.00 2/2/2008 06:30 Safety SIMOP's with Production & Construction. PTSM with Pollard, Production & Drills/Meetings McKinley 1 12/2/2008 06:30 3.0012/2/2008 09:30 Standby 1 Working decks with construction to get all needs covered for unenterrupted th slickline operations on South National crane. Spotted Methanl for use. Pulled a well bay hatches and put bridge grafting in place. Covered area with tarps to hold heat in upper well bay. '2/2/2008 09 :30 2.00 2/2/200811 :30 Slickline - Rig Up / 1 Rig up wireline. MU 2.25 "x T 7" DD Bader w/ Flapper Bottom, 1.5" X0 5', � Test BOPs / Rig ` 13/4" X 7' spangs, 1.75 "x 4' jars, 2 each 5' 1.75" wt. bar. 1.75"x 6" rope I Down Test socket Note oil jars and XO both have 13/8" fish neck. All others fish necks are 13/4 ". 2/2/2008 11:30 1.00'12/2/200812:30 ,Slickline - Rig Up / Eat lunch. Pressure test lubricator using methanl and water solution to Test BOPS / Rig prevent freezing 250 low & 2500 high - Good Test. 1 Down Test i 2/2/2008 1 2:30 1.5012/2/200814:00 Sliekfine - Bailing RIH with 2,25" DD Bailer to 7443' RKB did not identify fluid level or any obstructions on way in hole. Work bailer twice and getting extra P/U weight. Assume we may be getting along side SWS Pert Gun Fish. POOH, 3/4 Bailer full of solids Gra Clay looking returns and no sand noted in sample). We will send sample y to town analyses. 1 1 1 2/2/2008 14:00 1.50 2/2/2008 15:30 Slickline - Gauge RN with 2 .78" GR to 7444' RKB with no problems noted. POOH. Note no Ring extra P/U weights or losses noted on trips. 2/2/200815:30 1.50 2/2/2008 17:00 Slid cline - Run or Pull RIH with 31/2 X -Line for depth verification. Identified X- Nipple at 5426' RKB Plug or Stop in string to be 5418':WL (this is within normal slickline depth variation and I shotiow as normal), 2/2/2008 17:00 3.00 2/2/2008 20:00 ,Slickline - Rig Up / 'Consult with town on findings. R/D Pollard slickline and send home crew. ,Test BOPS / Rig Down Test 1 2/2/2008 20:00 4.00 2/3/2008 00 :00 Standby Call town to Mobs out SWS Eli Guns are on loactiorn and Packer - we need ( ' I unit, gen set, dog house with dump bailing equipment. All set up for 07:00 Hr I load out tomorrow. 2/3/2008 00:00 6.00.2/3/2008 06:00 Inactive*" 1SWS loaded out equipment on beach to OSK for load out. 2/3/2008 06 :00 6.00 2/3/200812;00 MOB** Working with production and construction trying to make room for SWS Eline and SWS Coil to both be on board at the same time. Construction has decks covered quite well on their own. Prepared all backload for OSK. Moved items for production and construction. SWS Elkus crew on board by 11:30 his 2/3/2008 12:00 4.00 2/3/2008 16:00 MOB" , I Worked the boat and got heavy picks on board south end just prior to lossing I i tide. Had to wait on flood tide to run. Finished working everyones back load and got our SWS equipment trasfered between decks and cranes. 2/3/2008 16:00 2.00 2/3/2008 18:00 Eleclridine - Rig Up / -15 below zero and wind blowing 25 knots. Got gen set spotted and finny Rig Down I got Erste Unit started after warming up. Got tools and lubricator laid out. I 2/3/2008 18:00 1.00 2/3/2008 19:00 Electricline - Rig Up / Break crew to eat and warm up. Rig Down 2/3/2008 19:00 1.50 2/3/2008 20 :30 Electricline - Rig Up / " rigging up lubricator and grease. Pressure test 250 low 2500 high with Rig Down I Imethantwater mix for cold weather. Good Test. 2/3/2008 20:30 3.0012/3/2008 23:30 ,Log - GR/CCL P/U SWS Dummy run with CCL. (2.5" 1.5" long Bull nose, 1 11/16" X 1,5' 1 1CCL, 2 1/8" X 6' Wt bar, 1 3/8" X 1.5' R.S.) Estamated weight 165#. RIH tied into SWS SCMT Log dated 11- 22 -07. RIH at 2000' /Hr and set down at 7377'. P/U and tied into 5" liner pup joint at 7010'. RIH again at 6000' /Hr and again ;tagged up at 7377'. Note no extra P/U off bottom on runs. (Appears as ' ,though slickline measurements are in error by 67' ?. POOH 2/3/2008 23:30 ' 0.50'2/4/2008 00:00 I Inactive" i IUD SWS lubricator and install night cap. S/D for night 2/4/2008 00:00 6.0012/4/2008 06:00 1nnactive" No Operations. 2/4/2008 06:00 i 0.50 2/4/2008 06:30 Safety ISIMOPS Drills/Meetings • • Chevron Chevron - Alaska Time Log Summary Sort Well Name --- - - -__- '., Field Name - -_- - - - - -- API/UWI ---- - - -_ -- Lease /Sena) CHEVNO License No. /Prope..,Ong KB Elev (ft. '.,Water Depth (ft) '.. M -17 McArthur River Field 507332055200 ADL017594; LB2629 2071200 79.2 185.00 Staff Date Our (hrs); End Data Asdvity Bit/Csg.SZL - _ -- Comment. - -- 2/4/2008 06:30 11.50 2/4/2008 18:00 Preparations ** Schlumberger Coil & cmters out for for site vist & chk equipment lay out - Work thru issues with DSM's having SLB set up for 24hr operations 2nd crew do 2 -6-08 pm - ordered N2 - set up boat for load out for CTU & equipment 2 -5 -08 - Work with production on well fluid returns & options for coil tbg clean out 2/4/200818:00 6.0012/5/2008 00 :00 Inactive I ; No operations 2/5/2008 00:00 6.00 2/5/2008 06:00 I Inactive Shut do for crew rest 2/5/200806 :00 0.5012/5/200806 :30 1SafetyMeetings 1Simops 2/5/2008 06:30 14.50 2/5/2008 21:00 Preparations Continue work coil tbo issues - went over drilling equipment back load w/ crane operater - measure bop stack & cellar opening for supt - Clean & clear deck & prep for coil tbg equipment & brk tour with crane operators & riggers - SLB crew on board @ 1800 hrs wait on boat 2/5/2008 21:00 3.0012/6/2008 00:00 Rig Up , }Unload coiled tubing unit and spot same cover reel with tarp start generator 2/6/2008 00:00 1.00 2/6/2008 01:00 Equipment - Offload Continue off load boat #1 of CTU equipment, spot same plug in head bolt heaters, Tarp & heat coil & batcher mixer 2/6/2008.01:00 5.00 2/6/2008 06:00 Inactive 1 I Send coil tbg crew to bed & night crane crew mointor heaters & warming of i ! egtnpmeM 1 2/6/2008 06:00 0.50!'2/6/2008 06:30 !Safety Meetings Simops w/ production & construction 2/6/2008 06:30 1.5012/6/2008 08 :00 `Inactive IContintre rest coil crew & crane crew mointor heaters warming of equipment 2/6/2008 08:00 13.50 21:30 Rig Up PJSM w/ SLB & crane crew & go over days plan - SLB coil crew start tum key 1 r /up - Continue warm equipment offload boat #2 all coil equipment on board @ 15:30 hrs - SLB coil night crew on board @ 1400 hrs - Continue spot & r /up equipment 2/6/200821:30 f 2.50 2/7/2008 00:00 1Rig Up Continue tum key rlup - Brk tour w/ coil crew to run 24 hr operations - PJSM start r /up on to well head 2/7/2008 00:00 6.00 2/7/2008 06:00 ( Rig Up Continue r /up - Finish m /up of riser - set 4 -1/6" Quad bop stack - Run hyd 1 1 lines to same - Run drill water line to batch mixer - r /up suction manifold to G pump - 2/7/2008 06 :00 0.50 2/7/2008 06 :30 1Safety Meetings I Simops w/ production & construction 2/7/2008 06:30 11.00,2/7/2008 17:30 Rig Up Complete r /up of hard line & hook up to G pump - Thaw batch mixer manifold valves - load batcher w/ 100 bbls drill water & heat same w/ steam - work on !CTU compruter - work on control cab remote controls to pump (no go run 1 manully) 2/7/200817:30 2.0012/7/2008 19:30 iBOP - Test !Test bops 250.4000 psi w/ test stick & chart same (state witness was waived by Jim Reggs} 2/7/2008 19:30 4.50 2/8/2008 00:00 ! Rig Up M /up horses head on to injector head - Stab coil - check moving parts - had trouble with chain oiler. Fixed problem (30 min). 2/8/200800 :00 1.50 2/8/2008 01:30 (Rig Up (Continue work on injector head: 12/8/2008 01:30 2.50 2/8/2008 04:00 BHA - PU M /up Bha #1 & pull test connector Bha Consists of 1- 3/4 " "x8" jet -swirl nozzle, 1 2 "x6" XO, 2.05 "x6.5' stinger, 1.99 "x8" XO, 2.13 "x19" baker disconnect, I 12.07"x8" XO, 2.12 "x14" double check valve and 1.75 "x1,5" roll on connector 2/8/2008 04:00 i 1.00 2/8/2008 05 :00 `BHA - Inspect/Test 1 Stab injector & test U 3500 psi (Ok) 2/8/2008 05:00 3.00 2/8/2008 08:00 Trip - Trip in Equilize pressure @ 800 psi open well & lubricate 18.5 bbls into well & open ! flow line - Attempt rih @ 1 bpm (production having problums w/ rate) Rih tl I 7000' noting jewerly & chking weights varying rate & speed to acommadate production 1.50 bpm @ 2600 psi w/ 214 psi WH pressure was best they could I ! handle 2/8/2008 08:00 1,00 2/8/2008 09:00 Circulate - Circulate f 'Add J-313 to Drill water & circ coil volume 1.75 bpm C 1650 psi WI 210 psi & Condition WH pressure 2/8/2008 09:00 1.0012/8/2008 10:00 Trip - Trip in Dn pump & rih & dry tag @ 7294' CTM RKB - P /up 50' shut in flow line & pressure well up to 1000 psi rih & dry tag @ 7296' CTM RKB - Had 4000 # over pull & lost 117 psi - Pooh 50' & pressure back to 1000 psi - Rih & 2nd dry I tag @ 7295' CTM RKB P /up 30' w/ same 4000 # over pull 1 2/8/2008 10:00 0.50 2/8/2008 10:30 Clean Out Open flow fine & bring pump on line © 1.75 BPM & attempt to clean out 16 tag solid @ 7296' & un able to clean out same 2/8/2008 10:30 2.5012/8/2008 13:00 :Trip - Trip Out of POOH 300' w/ pump @ an idle - discuss options w/ town - continue pooh & 1 Hole dis place coil w/ 60-40 methenol mix for freeze protect 1 2/8/2008 13:00 1.00 2/8/200814:00 Rig Down ? Rig injector off well. Take BHA off coil. Keep heaters on equip that can freeze I up, 2/8/2008 14:00 3.00 2/8/2008 17:00 Move - Unit Wait on Pollard slickline to gather tools up. Move equip around so slickline ! can rig up to the well. 2/8/200817:00 0.5012/8/200817:30 Safety Meetings 1 Simopsw /production. 1 2/8/2008 17:30 0.50 , 2/8/2008 18:00 'Safety Meetings 1 PJSM w /Pollard, Schlumberger and crane operator. Review pumping flamable fluid safety checklist. 2/8/2008 18:00 4.50 2/8/2008 22 :30 Rig Up Spot equipment, lubricator and MU 2.25"x5' 01) bailer, 1- 3/4"x5' spangs, 1- 3/4"x3' mss, 1- 3/4'x8" KJ, 1- 3/4"x10' stem, 1-S/4"x8" KJ and 1- 314"x8" rope socket, Pressure test lubricator to 250 psi low and 2500 psi high. Change out ` spooling head wheel. 2/8/2008 22:30 1.50 2/9/2008 00:00 Slickline - Work Ran in hole with 1.25" drive down bailer w /muleshoe flapper bottom and sat down on obstruction at 7374' RKB (slm). Bailed on obstruction and did not 'make any hole. Had about 50# to 100# overpull each time we bailed. POOH. 2/9/2008 00 :00 0,50 2/9/200800 :30 ti ISckline - Bailing Cont to pull out of hole w/225" bailer. Bailer had 6-10" of moist putty like 1 cement in it. 2/9/2008 00:30 1.50 2,2/9/2008 02:00 Slickline - Bailing RIH w/2.5" bailer and bail on obstruction at 7374' RKB (slm). POOH. Bailer 1/2 to 3/4 full of moist and wet cement like putty fill. 2/9/2008 02:00 4.00 2/9/2008 06 :00 '}Rig Up / Rig Down ** Rig down Pollard slickline and lubricator:. Move equip out of the way and set Schlumberger equip back in. Continue to monitor and warm Coil Tubing Equip and rig. 2/9/2008 06:00 0.50 06:30 'Safety SIMOPS Drills/Meetings 2/9/2008 06:30 0.5012/9/2008 07:00 Safety 1 PJSM w /Schlumberger and crane operator. Drills/Meetings • • Chevron Chevron - Alaska IWO Time Log Summary Sort Well Name Field Name API/DWI Lease/Serial CHEVNO License No. /Pmpe... ,Ong KB Elev (ft ...'Water Depth (ft) M -17 McArthur River Field 507332055200 ADL017594; LB2629 2071200 79.2 185.00 - - Start Date Our Ors) _ .. End Data Activity - ,aitlCeg Sz Continent 2/9/2008 07:00 . 15.50,2/9/2008 22:30 Preparations "" Continue to monitor and heat CT equipment and heat rig. Have MagTech mechanic out to work on 2 heaters. He fixed both. Have 2 Schlumberger mechanics out to work on equipment. Wait on Weatherford coil BHA and man to come from North Slope. 2/9/2008 22:30 0.5012/9/2008 23:00 Safety � PJSM w /Schlumberger Coil Crew and Crane Crew. Review pumping namable 1 �Driils/Meetings fluid safety procedures and checdtst_ 2/9/2008 23:00 1.00 2/10/2008 00:00 Preparations** Change out stripper rubber, cold temperatures making it hard to put new stripper rubber in stripper. 2/10/2008 00:00 5.00 2/10/2008 05:00 CCoil Tubing - Rig Up / `Continue to change out stripper rubber. Check and make up BHA #2. Rig Down (Consists of Weatherford toots - 2- 1/8"x1.6' (at 4.151" OD) underreamer, 2- 1/8"x11.27' motor, 2 -1/8 "x2.17' MHA, 2- 1/8"x7.7' dual jar, 2.2"x1' dual i check, 1- 3/4"x6" coil connector. Pressure test to 3500 psi (good). Stab injector on lubricator and re -claim methanol from reel to tank for freeze protect. 2/10/2008 05:00 1.00 2/10/2008 06:00 Coil Tubing - Rig Up / Pressure test lubricator to 3500 psi (good). 1. Rig Down ,2/10/2008 06:00 0.50 06 :30 Safety SIMOPS Drills/Meetings 2/10/2008 06:30 1.50 08:00 gripping In Equlize lubricator @ 80 psi Open well & flow line - Rih dry T/ 5600' CTM RKB Brk circ & pump 10 bbls Hot drill water & dn pump 2/10/2008 08:00 2.502/10/200810:30 Coil Tubing - Clean f I PJSM - Build 30 bbl high sweep © 2.5 PPB N -vis sweep- PJSM w/ Out (production on pumping bleach 2/10/2008 10:30 0.50 2/10/2008 11:00 Coil Tubing - Clean Brk circ & pump 5 bbls hot drill water - dn pump - Rih & dry tag top of fill @ Out 7338' CTM RKB 2/10/2008 11 :00 I 6.00 2/10/2008 17:00 Coil Tubing - Clean I glean out soft fill from 7338' RKB, (cm) to 7399' RKB (ctm) in 15' -20' Out I increments, chasing MI up hole with 8-10 bbl sweeps at 70 fpm to 5600' RKB 1(clrn). Rate was 1.5 bpm. Circulating pressure was around 3100 psi w/ dri l (water and dropped 10 2400 psi when we changed to seek water. Weir heed pressure was between 300 to 380 psi. At 7399' RKB (cm) motor staffed. At our calculated footage that would be the wireline fish. Dropped ball, sheared circ sub and circulated at 1.5 bpm (alt production could stand) from 7399' RKB 7 washing GLM's, to surface. Production treated 1 (kin) at 0 fpm, stopping and i I returns with a total of 4 bbls of bleach. There was never arry hard fiM. After dropping ball, circulating pressure was 1600 psi. Got all tools back and under- reamer blades indicated they worked ok. ■ NOTE: E4ine had tagged at 7377' RKB per tie-in log. Wirotne fish top is at 7438' RKB. That is 61'. This is how we came up with the reason we said we tag wireline fish at 7399' RKB (ctm). 7338' (top of tiff) plus 61' = 7399' where we stalled motor out. 2/10/2008 17:00 2.5012/10/2008 19:30 Coil Tubing - Rig Up / Rig injector off well - break & inspect BHA (ok) - Displace coil w/ 60/40 I Rig Down 1 methonal water - Secure well and coil tbg equipment - Send in coil crew 11 except one hand i 2/10/2008 19:30 4.50 2/11/2008 00:00 Monitor Re- arange equipment & spot E-lme equipment & warm same for r /up - Mointor heaters for warming equipment 2/11/2008 00:00 6.00 2/11/2008 06:00 Preparations** Crane crew cont to monitor heaters and warming equipment. Move unneeded 1 coil equipment from south pipe rack and prep for boat. 1 2/11/200806 :00 0.5012111/200806:30 Safety SIMOPS I Drills/Meetings ' 2/11/2008 06:30 7.50 '2/11/2008 14:00 Preparations' Schlumberger coil man on location started E -line unit and generator while waiting on Schlumberger wireline crew to ride boat out to platform. Helicopters down due to weather. 2/11/2008 14:00 1.00 2/11/2008 15:00 Preparations" Schlumberger arrived on platform at 1400 hrs. Back load boat with some coif equipment and personnel, 1 1 2/11/2008 15:00 0.50 2/11/2008 15:30 Safety SIMOPS and PJSM w /Schlumberger and crane crew. Review pumping Drills/Meetings flammable fluids safety checklist. 2/11/200815:30 2.00 2/11/200817 :30 Electricline - Rig Up / Mobe a -line unit on deck. Rig up lubricatorw/2. 5x1.7' but plug, 1- 11/16"x23" Rig Down CCL, 2 -t /8"x6' wt bar, 1-11/16"x1' rope socket. Pressure test lubricator to 250 psi low and 2500 psi high. 2/11/200817:30 2.00 2/11/2008 19:30 1 Log - GR/CCL Run in hole w/2 -1/2" bull nose, tie -in to Schlumberger SCMT log dated 1 11/22/07 and tag bottom at 7430.5'. POOH. 2/11/2008 19:30 1.0012/11/2008 20:30 Cement - Set i Warm up and test posi -set setting tool I Retainer 2/11/2008 20:30 3.50 j 12/12/2008 00:00 Cement - Set I MU 1.6875 "x7.5' posi -set plug and setting tool. Run in hole with plug, tie -in to 1 Retainer ! Schlumberger SCMT log dated 11/22/07. Tag fill at 7430.5'. Get tool pick -up ! 1 wt and set top of posi -set plug at 7423'. It took 18.5 minutes to set. Picked up 1 25' ana wenf5ack down and tagged lightly. POOH. Tools looked good. 2/12/2008 00:00 5.00 2/12/2008 05:00 Cement - Set Continue POOH, All looks good with tools. Lay down lubricator, Secure well Retainer with night cap and lay down Scllurnberger for rest. 2/12/2008 05:00 1 1.00 2/12/2008 06:00 Safety Simops w/ Production & construction - PJSM w/ crane crew & SLB hands Drills/Meetings 2/12/2008 06:00 I 1.00 2/12/2008 07:00 Preparations 1 Prep Sclumberger Positive displacement dump Bailer for 32' water dump. MU 2 1/8"x 36' dump bailer, 2 1/8"x 7' weight housing, 1 11/16"X 26" deployment I head, 1 11/16"x 26' CCL, 1 3/8"x 22' rope soc ket,Bottom fill with platform I. water. j 2/12/2008 07:00 1.50 12/12/2008 08:30 Cement - Mix/Pump RIH correlate to SCMT log dated 11/22/2008, short joint at 6990' to 7011'. Continue in well tag possiset plug at 7423' pull up 2' and dump water.POOH 2/12/2008 08 :30 1.50 2/12/2008 10:00 Cement - Mix/Pump Cement run #1 RIH correlate to SCMT log, continue Rift tag plug pick up 1' and attempt to dump cement pug up slowly 10' stop and wait 3 minutes. t !POOH. Bailer did not dump empty bailer and inspect. Cement in bottom nose j prevented shear spew from shearing. i ■ • Chevron Chevron - Alaska Time Log Summary Sort Well Name '.Field Name API /UWI Lease /Sena) CHEVNO `License No. /Poppe... Ong KB Elev (ft -1 Water Depth (ft) M -17 McArthur River Field 507332055200 ADL017594; LB2629 2071200 79.2 185.00 1 2 End Cement - Mix/Pump smcs Discuss increasing bl e scrn cement of ement w/crew, Ceme H 2/12/2008 10:00 1.5012/12/2008 11:30 Cerecommend r l on er bl dump end after and and fill w/ Start bete Dur (far) _ _ rew, _ m Discus blending longer after cement. RIH correlate continue in hole tag plug, pull up 1' and dump cement. POOH. Good Dump 2/12/2008 11:30 !, 1.00 !2/12/2008 12:30 Cement - Mix/Pump 1Cem t run #2 Fill dump bailerRlH correlate continue in hole to 5' above plug depth of 7423' dump cement POOH. Good Dump 2/12/2008 12:30 I 2.0012/12/2008 1 1 14:30 'Cement - Mix/Pump Cement run #3Fill bailer w/ cement run in well correlate, continue in well and dump cement 10' above top of plug at 7423' POOH. Total of 3 cement runs for a 15' cement plug. Total of 15.25 gals. dumped. Ton of Cemyptplua at 7405 + / -. Cement in place at 14:00 hrs Feb. 12, 2008 2112/200814:30 2.00 2/12/2008 16 :30 Electridine - Rig Up / I Rig down E -Lane short as they will be first on the well after cement cures. :Rig Down I All passes were conetated to Schlumgberger SCMT log dated 11/22/2007. 2/12/2008 16:30 7.5012/13/2008 00:00 Cement - Waiting ** Wait 18 hrs on cement for tag. Spot Nitrogen pump and Nitrogen tank in preperation for blow down. Tubing Presure - 0 psi, 7 "x 3.5" annulus - 200psi, 9 5/8 "x 7" annulus - 175 psi, 13 3/8 "x 9 5/8" annulus - 0 psi, 28 "x 13 3/8" annulus - 80 psi. 2/13/2008 00:00 5.0012/13/2008 05:00 Cement - Waiting" [Wait on Cement, Sdumberger e-tine crew rest, night crane crew to monitor ■ [equipment 2/13/2008 05:00 1.00 2/13/2008 06:00 Safety Simops w /production & Construction, hold PJSM w/ production and crane 1 :Drills /Meetings ' 2/13/2008 06:00 1.00 2/13/2008 07:00 Efectridine - Rig Up / 1 Rig up Schlumberger E- line and MU 2.5 "x 1.6' bottom nose, 1 11/16 Rig Down I 'x21" CCL, 2 1/8"x 6' wgt bar 1 3/8 "x 22" rope socket. Make up on coil tubing o- BOP. 2/13/2008 07:00 1.50 2/13/2008 08:30 Log - GR/CCL RIH correlate to sws SCMT log dated 11/22/2007 continue in well and tag top of cement at 7405' RKB (E -Line measurement.) 2/13/2008 08:30 1.00 2/13/2008 09:30 Electridkre - Rig Up / Rig down and stand back E- line.Prep deck space for coil operations. E-kne I Rig Dorm I crew to beach at 10:30 1 j, 2/13/2008 09:30 3.00 2/13/2008 12:30 Coil Tubing - Rig Up / Rig up coiled tubing to lay in 20 bbl 6% KCL Dill an olan weij re w/ N Rig Down 2/13/2008 12:30 0.5012/13/200813:00 ISatety I ISimops w/ production and construction personnel for coil operations. IDrkls/Meetings 2/13/2008 13:00 0.5012/13/2008 13:30 1Coil Tubing - Rig Up / 'Pressure test stack, 400 psi low / 3500 psi high. Bleed psi to 180 psi. RIH, tag 1 Rig Down Iswab. Set elect. counter to 69', mechanical counter to 0'. 2113/200813:30 1.50 2/13/200815:00 f Coll Tubing - Tripping j Open well, RIH w/ BHA =1.75" roll on CTC, 2" o.d x .9375" Id. x .125', DBPV= 2.12"x 1.1 "x 1.15', MBPT= 2" x 1" x 5.5, JSN = 2.3" x .75" x .65' total length = 7.425' ) circulating 6% KCL to nozzle w/ drill water at .45 bpm, whp= 1654. Wt. ck. at 5000' =11, 500 # on both mech. and elect. indicators/ riw = 3000#. Wt ck at 7250' = 21,000# on mech., and 15,500# on elect. I indicators / nw = 4500#. WHP slaying Constant at 185 psi. KCL at nozzle, stop l 1 elect CTM. PUH, ' at 7,401' D cement at 7;405 up !pumping. Dry tag top 1 EECTM. 2/13/2008 15:00 0.5012/13/2008 15:30 Circulate & Condition I Nozzle at 7,400' ECTM, circulate 5 bbls. KCL pill out nozzle at 1 bpm, 1,800 Icirc. psi, whp = 165 psi. PUH at 1:1 ratio laying in remaining 18 bbls KCL with (drill water. All KG out of nozzle at 6300'. S/D pumping and cont. PUH to 3500'. PT N2 lines to 500 / 4000 psi. Start displacing water from reel w/ N2, park coil 1 at 3500'. 1 2/13/2008 15:30 i 2.50 2/13/2008 18:00 Nitrogen Lift I Coil parked at 3500', N2 at surface. ht2 rate 1000 scfm 81 1,680 psi / WHP = 200psi RIH taking 1000' bites to 7,100'. Park coil and continue lifting fluid. 2113/2008 18:00 1.00 2/13/2008 19:00 Coil Tubing- Tripping 94 bbls. retumed to surface (tubing x CT annulus + coil volume ). POOH pumping N2 at 1000 scfm, 1200 kirk. psi, whp = 170 psi. N2 tank empty at I 2100', total retums = 98 bbls. 2/13/2008 19:00 ` 5.00 2/14/2008 00:00 Coil Tubing - Rig Up / Rig down SLB CTU Rig Down 2/14/2008 00:00 6.00 2/14/2008 06:00 Coil Tubing - Rig Up / Complete r /dn CTU. Demob and back load on boat. Rig Down 2/14/2008 06:00 0.50 2/14/2008 06:30 Safety 1 Slb. e-fine crew onboard. Simops w/ production and construction crews Drkis/Meetings concerning perforating operations. 2/14/2008 06:30 1.501 2/14/2008 08:00 Electricline - Rig Up / Prep for r /up a -line. Start Equipment to warm up. Rig Down 2/14/2008 08:00 0.50 2114/2008 08:30 Safety I ;Hold PJSM, and review perforating JSA w/ Slb. and production personnel. Drdis/Meetingsr 2/14/2008 08:30 1.5012/14/2008 10:00 Electricline - Rig Up / R/up Slb. e-line unit. Mu 2.5" x 12' HSD gun, 25" x 21" f.h., 1 11/16" x 18" Rig Down ,CCL x 1 3/8" rope socket. Arm perf gun, go to well. 2/14/2008 1000 1.00 2/14/200811:00 Electridine - Rig Up / I Press. test stack to 500 psi / 3500 psi, open well and RIH. Rig Down 2/14/2008 11:00 1.50 12/14/2008 12:30 Perforation - Initial RIH and correlate to SLB SCMT log dated 11/22/07 at short joint 6990' - 7011', continue in well tag cement top at 7404' and log strip. drop back down and log Iinto position CCL at 7285.T . Tubing Pressure 305 PSI, Perforate 7296'- 1 7308' pressure build about 1 psi a minute. POOH 2/14/200812:30 3.00 2/14/2008 15:30 Monitor Secure well and turn over to production. Tubing pressure at 312 psi. Flow welt 1 at 17:30 12:30 Flow rate 1.2 MMCF Pressure 60 PSI 13:00 1.3 MMCF 60 PSI 13:30 1.2 MMCF 60 PSI 14:00 1.2 MMCF 59 PSI` 115:00 1.1 MMCF 59 PSI • • Chevron IWO Chevron - Alaska Time Log Summary Sort Well Name F ield Name - - API /UWI Lease/Senal CHEVNO License No./Prope...: Orig KB Elev (ft... Water Depth (ft) M -17 McArthur River Field 507332055200 ADL017594; LB2629 2071200 79.2 185.00 2/14/2008 15:30 OW 150 8 0 17 I 17:00 Perforat -I nitial IBS MU 2.5 "x 30' Powerjet Omega 6 SPF, 0 d egree phased gun. RIH correlate to SLB SCMT log dated 11/22/07 tag bottom at 7402' (2' of fill) log strip drop back to bottom and place gun on depth CCL at 7357.4' Ton %hot 7361'- 7341' Tubing pressure at 284 psi. Fire gun. Tubing pressure increase of 2 psi POOH. Tubing pressure after gun at surface 289 psi. 2/14/2008 17:00 0.50 2/14/2008 17:30 Electricline - Rig Up / Secure well and tum well to production. Rig Schlumberger down to drill deck i 1Rig Down and get prepared for power spiral perf. 2/14/2008 17:30 6.50 00:00 'Monitor Well Monitor well. Flowing at 90 PSI and 1.6 MMCF. Pretty steady at that rate and pressure. Boat arrive Backload boat with AK Heaters, Hose Basket, and other misc.Boat out at 22:45. Flow rate decrease at 21:40 to 1.1 MMCF and 87 PSI Flowing Tubing Presure - 89 psi, 7 "x 3.5" annulus - 80psi, 9 5/8 "x 7" annulus - 175 psi, 13 3/8 "x 9 5/8" annulus - 0 psi, 28 "x 13 3/8" annulus - 80 psi.. Plan forwarg: Fly SLB 2.5" 5 spf, 45 degree pendalum gun stuff and gun loader out tomorrow after charges arrive and reperf with dee er penetrating 1 I gun. Charges are scheduled to be in in aftemoon so wl try an ge crew to beach in AM. No flights tonight due to weather. 2/15/2008 00:00 6.00 2/15/28 8;00 [Monies Well Flow wallet 90 PSI at1.5 MMCF at 00:15 well flowinf at PSI 1.1 MMCF. 1 Well was down to 50 PSI and .4MMCF at 04 :30 Shut in. Pressure building 2/15/2008 06:00 1.00 2/15/2008 07:00 Safety 1 SIMOPS w/ construction and crane crews. !Drills/Meetings 2/15/2008 07 :00 2.00 2/15/2008 09 :00 Monitor Well 1Cafi town tow and discuss running Pressure test, Wait on confirmation to run Pressure Temperature log. Monitor well, presure buid to 291, psi. l 12/15/2008 09:00 1.00 2/15/2008 10:00 Electricline - Rig Up / Rig up a -line to run pressure temperature log. MU 1 11/16 "x 7' Pres/ Temp 1 Rig Down !tool, 2 1/8 "x 6' wt bar, 1 11/16 "x 6' wt bar, 1 3/8 "x 22" rope socket w/ 5x3 Weak Point. PT 500 psi low and 3000 psi high. 2/15/2008 10:00 3.00 2/15/200813:00 Log RIH w/ well shut in 291 psi on tubing. Correlate to SLB SCMT log dated I PressurefTemperat... 11/22/07. Continue in well watching for fluid level at 6720', Tag Fill at 7398'. Survey Log across parrs and park tools at 65621'. Production to flow well at 1 mnncf. Flow for 5 min. and begin log down at 60 ft min., log to TO. Log up at 60 ft min. from 7398' to 5630'. Flowing fluid level at 6175'. Noted some annomolies across Squeezed perfs.Shut well m and POOH 1 2/15/2008 13:00 2.00, 2/15/2008 15:00 I Electricline - Rig Up / Rig down Schlumberger to drill deck and secure well. Schlumberger to build !Rig Down new rope socket and prepare upper well bay for gun loading. Call SLB gun loader, gun charges in Anchorage will be in Kenai around 16:00. 2/15/200815 :00 3.50 2/15/200818:30 {Monitor Welt Production pressure web up to 1000 psi w/ platform gas. Flow well to tie at 100 % in attempt to unload H2O; flowed for appoximatty 30 minutes Tubing pres. 5 PSI.Shut well in. 2/15/2008 18:30 5.50 2/16/2008 00:00 1 Monitor Well Monitor tubing pressure, building at 12 psi per minute up to 150 psi. Build 1 slowing down 19:45= 244 psi, some bleed at flow line. Production block well in at well head and observe pres. building 22:30= 272 psi. Weather hold at 1 Helliport, SLB gun loader and explosives at helliport at 17:00. Hellicoptor to 1 I platform at 22:30. Gun Loader attend platform safety orientation. Move sib 1 /equipment and explosives to upper well bay. Shut down for night. 2/16/2008 00:00 6.0012/16/2008 06;00 Monitor Lay Sir. E-line crew down for rest. Continue to monitor well. 1 2/16/2008 06:00 1.00.2/16/2008 07:00 !Safety SIMOPS and review PJSM and perforating JSA with production and Meetings/Drills construction personnel. 2/16/2008 07:00 4 2.00 2/16/2008 09:00 Electricline - Rig Up / 1 Rig up Sib e-lIne. M/u 10' x 2. 125" PSEJ (5 spf, 46 degree pendulum phase) Rig Down perforating gun, 1.6875" x 1.96' FH, 1.6875" x 1.5' CCL, 1.6875" x 6' Hyd. e -lore jars, 2.125" x 6' WS, 1.375" x 1.83' RS. 2/16/2008 09:00 1.50 2/16/2008 10:30 ,Tripping In Go to well, PT stack 300 low / 3500 high. Open well ( WHP= 500 psi) RIH with 1 gun run #1 2/16/2008 10:30 I 3.00 2/16/2008 13:30 Perforation Puti ilo in log frorn 7070 km 6935', using shoat joint at 7011' to 15990 for Reperforation. reference. Correllated to SCMT log dated 11/22/07. RIH, tag 68 @ 7366' CCL depth / 7382' end of perf gun depth. PUH logging to verify depth, stop 1 7212', no correction needed. RIH to 7373', PUH to 7365.1' CCL depth. ( f . ' interval 7381' to gun 7371') Shoot n, rig positive indication tha rep t gun filed 3 times, same resutts.POOH logging to 7270'. Gun hanging up © 535$' ( # 1 IGLM), work it lose, cont. POOH. Close swab, lay dam misfired gun. Investigation shows the ESIG initiated the EFI, but transfer between the EFI unknown. line, and check all nknown andtwnfnead failed, Reason Meg assembly corrections, all check good. kA/tj run #1 -A (an measurements same as run #1 Go to wen RIH. WHP = 463 per. I I 2/16/2008 13:30 2.5012/16/200816:00 Perforation - Pull tie in log from 7070' to 6935', using short joint at 7011' to 6990' for I Reperforation reference. Correllated to SCMT log dated 11/22107. RIH, tag fill @ 7366' CCL depth / 7382' end of perf gun depth. PUH logging to verify depth, stop @ 7212', no correction needed. RIH to 7373', PUH to 7365.1' CCL depth. (eel, I l interval 7381' to 7371'1 Shoot gun, good indication gun fired. POOH logging 1 to7270'. No problems pooh. Close swab, lay down gun. Gun strip looks good. M/U gun run #2 (all measurements same as run #1 -A) Go to well, RIH. WHP = 463 psi. 2/16/2008 16:00 1.5012/16/2008 17:30 Perforation Pun tie in W 9 grad log from 7070' to 6935', using short joint at 7011' to 6990' for Reperforation reference. Correllated to SCMT log dated 11/22/07. RIH, tag fin @ 7366' CCL 1 depth / 7382' end of pert gun depth. PUH logging to verify depth, stop © Pe 7212, no correction needed. RIM to 7373', PUH to 7355.1' CCL depth. rf interval 7371' to 7361' Shoot gun, good indication gun fired. WHP= 52 prsn an "m n .POOH) to7210'. No :..Close a cln { { uaky logging problems pooh swab, lay down gun. Gun strip looks good. • • Chevron IWO Chevron - Alaska IMO Time Log Summary Sort Well Name Field Name _ - -- ___ —- 'iAPI /UWI Lease/Senal _ CHEVNO '. License NO.IPmpe....Orig KB Elev (ft. Water Depth (fl) M -17 McArthur River Field 507332055200 ADL017594; LB2629 2071200 79.2 185.00 2/16/2008 17 :30 our 0012/16/2008 0 21:30 Perforation - Btu ( Prep for RIH. Problems with CCL t rouble s tool string, short in connection Reperforation between CCL and MPD. Repair and check fire. 2.5 HRs. Make up 2.5 "x 10' Power Spiral gun 5 SPF 45 deg. Pendelum phased . RIH correlate on depth w/ SCMT log dated 11/22/2007. Log into position CCL depth7292.1' RKB, Interval 7298' - 7308' RKB Fire gun. ( good indication) POOH. 2/16/2008 21:30 1 1.5012/16/2008 23 :00 1 Eleckicline Rig Up /', 'Rig down Schlumberger to drill deck. Secure well and Schlumberger to rest li Rig Down 2/16/2008 23:00 I 1.00, 2/17/2008 00:00 Monitor Well Flowing Tubing Presure - 80 psi, 7 "x 3.5° annulus 15 psi, 9 5 /8"x 7" annulus - 180 psi, 13 3/8 "x 9 5/8" annulus - 0 psi, 28 "x 13 3/8" annulus - 85 psi.. 2/19/2008 00:00 6.00 2/19/2008 06:00 'Inactive" Schlumberger and DSM on 04:30 flight to platform, Onboard 05:15 get Hotwork permit and warn equipment. 2/19/2008 06:00 1.50 2/19/2008 07:30 1 Safety SIMOPS w/ Constructio, production and crane crew, discuss todays Drills/Meetings operations. PJSM w/ Production and crane crew, review wireline safety checklist and Unocal Explosive safety checklist, Determine who to contact to open and close swab. Review pumping flammable liquids checklist. 2/19/2008 07:30 3.50 2/19/2008 11:00 {ElecMcline - Rig Up / ( Rig up Schlumberger E -line, build 5x3 wp and stab riser 011 well. Build 14'X Rig Down 2.5" Power Spiral EJ 5 SPF 45 degree phased gun.Make up 25"x 1 11/16" Safe housing, 23"x 1 11/16" MPD, 18"x 1 11/16" CCL, 6.2'x 1 11116" Jars, 2 1/8"x 6' wgt bar, 1 3/8"x 22° rope socket. Pressure test well 250 psi tow and 1 2500 psi high. Begin pressuring up well w/ platform gas. Wait on chopper. 500 PSI on tubing. - Note it looks like btm perfs started taking pressure at this pressure - Talked to Anchorage Engineering and got the OK to perforate at this surface pressure 2/19/2008 11:00 2.00,2/19/2008 13:00 Perforation - Initial Gun Run #1 MU 2.5 "x 14' Power Spiral EJ, 5 SPF, 45 deg phased to tool string. RIH, Correlate to SLB SCMT log dated 11/22/2007 across short joint at 5750'- 5771'. Run back in well to 5950' and log into position CCL depth 5836', Top shot at 5842', Bot shot at 5856': Fire gun, (mediate increase in presure from 470 psi to 780 psi. POOH Tubing Pressure at 13:00= 832 PSI. 2/19/200813:00 1.00 2/19/200814:00 iPreparations"" Break down old gun Bottom 4' of Gun strip let in well, looks like the screws blew off at the splice. Finish building Gun #2. Check fee and CCL. Arm Gun #2. 2/19/2008 14:00 1.5012/19/2008 15:30 Perforation - Initial Gun Run #2 RIH w/ 10' 2.5" Power spiral, 5 spf gun. Correlate to SLB SCMT log dated 11/22/2008. Place gun on depth 5832'- 5842' as per Final approved perforation request form dated 2/18 /2008. Tubing presure 832 PSI. Fire gun pressure increase to 837 psi and then fell back to 832 psi. POOH 1 2/19/200815:30 2,00 2/19/200817:30 Monitor Welt Rig Schlumberger down 10 ddItdeck, Secure well and stand bye. Production flour well to test. Shut in tubing pressure 835 psi. Flow well to Flare at 3.3 MMSCFD rate 795 •�' After 45 minutes switch 10 sales *'*q" i rate at'796 To r .TTZ?mEr ra • 2/19/2008 17:30 2.502/19/2008 20:00 Electricline - Rig Up / Rig down Schlumberger and package for transfer to King salmon. Three items Rig Down to beach. Clean area and prepare to go to beach. 2/19/2008 20:00 4.00 2/20/2008 00:00 flnactive "• Schlumberger 10 OSK. Joe to house. Flowing Tubing Presure - 793 psi, rx 3.5" annulus 20 psi, 9 5/8 "x 7" annulus -175 psi, 13 3/8x 95/8" annulus - 0 psi, 28"x 133/8" annulus - 80 psi.. Chevron • Chevron - Alaska Daily Operations Summary Well Name Field Name API /UWI Lease /Serial Orig KB Elev (ftKB) Water Depth (ft) M -17 McArthur River 507332055200 TRADING BAY UNIT 79.2 185.00 Primary Job Type Primary Wellbore Affected Drilling - Original Original Hole Jobs Type Jo. at AFE No. Objective Actual Start End Date QC Eng Drilling - Original Drill D7001 Drill and complete grass roots well in multiple grayling 10/14/2... 12/30/2... gas pay sands Daily Operations 10/14/2007 07:00 - 10/15/2007 00:00 Operations Summary 10/15/2007 00:00 - 10/16/2007 00:00 Operations Summary 10/16/2007 00:00 - 10/17/2007 00:00 SUPERSEDED Operations Summary ry / 10/17/2007 00:00 - 10/18/2007 00:00 1 �. Operations Summary 10/18/2007 00:00 - 10/19/2007 00:00 Operations Summary Finish centering up over slot Al -9. Continue with preparation of dri g equipment. Prep to rig up diverter system. 10/19/2007 00:00 - 10/20/2007 00:00 Operations Summary Continue to rig up 10/20/2007 00:00 - 10/21/2007 00:00 Operations Summary Rigging up. Change out diverter element. Modify bell nipple. Work on div: er controls and #1 pump fluid ends. 10/21/2007 00:00 - 10/22/2007 00:00 Operations Summary Rigging up. Continue to work on diverter controls and valves. Start mixing spu • ud. Complete repairs on bell nipple and iron roughneck. 10/22/2007 00:00 - 10/23/2007 00:00 Operations Summary Rigging up. Continue to troubleshoot diverter nd diverter controls. Repair topdrive • ntrols. 10/23/2007 00:00 - 10/24/2007 00:00 Operations Summary Rigging up. Perform AOGCC diverter test. Continue to prep for spud. 10/24/2007 00:00 - 10/25/2007 00:00 Operations Summary Rigging up. PU 5" DP and HWDP. Perform diverter drills with crews. Calibrate rigwatch s em. RU 6" overboard lines. 10/25/2007 00:00 - 10/26/2007 00:00 Operations Summary Rigging up. Test land 13 3/8 casing hanger w/o success. Repair hanger and repeat w/o succes Repair hanger and land sucessfully. Prep to spud. 10/26/2007 00:00 - 10/27/2007 00:00 Operations Summary Finish test running the 13 3/8" casing hanger. MU clean out BHA and TIH. Displace conductor to s• d mud. Attempt to survey w/ Gyro without success. TOOH to change out Gyro. 10/27/2007 00:00 - 10/28/2007 00:00 Operations Summary • Replace faulty Gyro. TIH and spud well. Drill 480' -903'. TOOH standing back. 10/28/2007 00:00 - 10/29/2007 00:00 Operations Summary Finish LD BHA. MU jetting BHA and wash out conductor. RU and run 13 3/8 casing to 893' w/o problem. Pre to pump stage 1 of 13 3/8 cement job. 10/29/2007 00:00 - 10/30/2007 00:00 Operations Summary Finish prep for cementing and start stage 1 cement job. Lost mix water. SD and investigate problem. Start MU r. • lacement mix water. 10/30/2007 00:00 - 10/31/2007 00:00 Operations Summary Cement 13 3/8" casing to surface in 2 stages. Start to ND diverter. 10/31/2007 00:00 -11/1/2007 00:00 Operations Summary ND diverter. Install 13 5/8" 5M multibowl wellhead system and test voids OK. Chevron • Chevron - Alaska Daily Operations Summary Well Name Field Name API /UWI Lease /Serial Orig KB Elev (ftKB) Water Depth (ft) M -17 McArthur River 507332055200 TRADING BAY UNIT 79.2 185.00 Daily Operations S E Me 11/1/2007 00:00 - 11/2/2007 00:00 ' Operations Summary Continue to nipple up BOP's • 11/2/2007 00:00 - 11/3/2007 00:00 Operations Summary Finish testing BOP's. Prep to PU BHA. 11/3/2007 00:00 - 11/4/2007 00:00 Operations Summary MU 12 1/4" BHA. TIH and drill out stage collar. Test sing to 1500 psi ok. Drill hard cement out of shoe track. Perform FIT to 12.8 ppg. EMW. Drill to 974' MD. 11/4/2007 00:00 -11 /5/2007 00:00 Operations Summary Directionally drill 974' to section TD at 1435'. Start running /8" casing. 11/5/2007 00:00 -11 /6/2007 00:00 Operations Summary Run 9 5/8" casing to 1430'. Cement 9 5/8" casing in 2 stages. I all 5" rams and test BOP. Prep to drill out. 11/6/2007 00:00 - 11/7/2007 00:00 Operations Summary Mix new mud system. MU drill out BHA and drill out ECP /stage tool. est casing to 2500 psi OK. Drill out shoe track and 20' of hole. Perform FIT to 12.8 ppg EMW. TOOH for directional BHA. 11/7/2007 00:00 - 11/8/2007 00:00 Operations Summary MU directional BHA while mixing mud. Test BHA. Drill 1455 - 2157'. 11/8/2007 00:00 -11 /9/2007 00:00 Operations Summary Repair PVT system problems. Directionally drill 2157'- 3572'. Collect pore press - point in the A2 sand. Pull 10 stand wiper trip OK. 11/9/2007 00:00 -11 /10/2007 00:00 Operations Summary RIH to 3572'. Drill from 3572' to 4620' with 9.1 ppg wbm. Take pressure test points a 1520, 3570, 3744', 4254' 4489' 11/10/2007 00:00 - 11/11/2007 00:00 Operations Summary Drill from 4620' to 5601' with 9.15 ppg wbm. Take pressure samples at 4854', 5023', 516 11/11/2007 00:00 -11 /12/2007 00:00 Operations Summary Drill from 5501' to 5710'. CBU and pump nut sweep. POOH and LD BHA. P/U cleanout BHA and make clean -out run. 11/12/2007 00:00 - 11/13/2007 00:00 Operations Summary RIH and wash and ream to 5710'. Pump sweep and POOH. Test 7" casing rams to 250/4000 psi. U to run 7" casing. 11/13/2007 00:00 - 11/14/2007 00:00 Operations Summary Run 7" casing to 5700'. Cement with 143 bbls 12.0 ppg Lite Crete with good returns. Test casing to 3506 Si. • 11/14/2007 00:00 -11 /15/2007 00:00 Operations Summary Finish R/D of casing equipment. Change rams to 3 -1/2" and 5 ". Test stack to 4000/250 psi. 11/15/2007 00:00 - 11/16/2007 00:00 Operations Summary Finish testing BOPs. MU 6 1/8" BHA and TIH. Drill out 7" shoe track. Perform FIT to 13.5 ppg EMW. Directional .611 5,73U-5,869'. 11/16/2007 00:00 - 11/17/2007 00:00 Operations Summary Directionally drill 5,869' to TD @ 7,670'. Circulate and condition mud for liner. 11/17/2007 00:00 - 11/18/2007 00:00 Operations Summary TOOH and LD 6 1/8" BHA. Start running 5 ", 18 ppf flush joint liner. 11/18/2007 00:00 - 11/19/2007 00:00 Operations Summary Finish picking up liner and hanger assy. TIH. Liner set down in the D2 coal at 5770'. Attempts to circulate resulted in packing o TOOH for clean out BHA. Hanger appears to be partially set. • • Chevron Chevron - Alaska Daily Operations Summary Well Name Field Name API /UWI Lease/Serial Orig KB Elev (ftKB) Water Depth (ft) M -17 McArthur River 507332055200 TRADING BAY UNIT 79.2 185.00 Daily Operations 11/19/2007 00:00 - 11/20/2007 00:00 UPWASEDK a Operations Summary Finish laying down 5" liner. TIH with cleano BHA. Wash and ream 5,700 - 7,317. 11/20/2007 00:00 - 11/21/2007 00:00 Operations Summary Complete wiper trip. MU liner and TIH to 6,562'. 11/21/2007 00:00 - 11/22/2007 00:00 Operations Summary Continue in hole with 5" liner. Work liner to TD. Circ ate and reciprocate slowly while conditioning for cement. Liner started to pack off and became stuck. Work stuck pipe and pack off problems. 11/22/2007 00:00 - 11/23/2007 00:00 Operations Summary Cement 5" liner at reduced circulation rates due to packing , ff. Pump 49 bbls LXT slurry @15.8 ppg. Maintain limited return for most of job. Ultimately lost comeplete returns. Land plug and set hanger. Attempt ' set ZXP packer w/o success. Sting out and circulate BU. Recover large quantities of coal fines in returns but no cement. TOOH. Find dog sub not she. ed in running tool indicating ZXP did not set. Clear floor and prep to LD 5" DP out of derrick. 11/23/2007 00:00 - 11/24/2007 00:00 Operations Summary Finish RD ELU. Lay down 5" DP and 3 1/2" HWDP. Strap and pre. e completion equipment. 11/24/2007 00:00 - 11/25/2007 00:00 Operations Summary Install 2 7/8" rams and test. PU 2 7/8" DP. TIH with 4 1/16" mill and 5" , -sing scraper to 3462'. 11/25/2007 00:00 -11 /26/2007 00:00 Operations Summary Complete 5" casing scraper run to landing collar at 7,545'. TOOH standing b k. Start BOP test. 11/26/2007 00:00 -11 /27/2007 00:00 Operations Summary Finish BOP test. RU ELU and prep to run CIBP. 11/27/2007 00:00 - 11/28/2007 00:00 Operations Summary Set CIBP at 6,260. Perforate 5" liner 6,234- 6,240. Set cement retainer @ 6, 216. RI LU. TIH with cement stinger on 2 7/8 DP. Sting into retainer and establish limited circulation. Sting out of retainer and CBU. H2S alarm on BU. Ci late through gas buster. Monitor well. OK. Start TOOH with DP. 11/28/2007 00:00 - 11/29/2007 00:00 Operations Summary FIH and sting into retainer. Work limited circulation problems behind 5" liner. Ultimately pac .ff at liner hanger assy. TOOH and pick up ZXP setting tool. TIH and set ZXP packer. Test Liner top to 3500 psi OK. TOOH. RU ELU in preparation , r perforating. 11/29/2007 00:00 -11 /30/2007 00:00 Operations Summary RU ELU and perforate upper circulation holes 5782 -5788. TIH and sting into retainer and establish ' culation through perforations. Attempt to work packing off tendencies with limited success. Perform circulation squeeze with 16.5 bbls of 15.8 ppg T G slurry. Some losses were experienced. Circulate out —5 -6 bbls cement after job. See detail for more information. Lay 7 bbls balanced cemen , lug across the upper perforations and squeeze 2 bbls away. Wash cement out of liner top. Circulate clean and TOOH. 11/30/2007 00:00 -12/1 /2007 00:00 Operations Summary TOOH for clean out assy. TIH w/ 4 1/8" clean out assy. Tag cement at 5677. Drill out cement plug to 5793. ' est perfs to 1250 psi for 30 min ok. Continue drilling out cement to 5860'. 12/1/2007 00:00 - 12/2/2007 00:00 Operations Summary Continue to drill out cement and retainer to 6245. Attempt to test lower squeeze perfs w/o success. TOOH for cem t stinger. 12/2/2007 00:00 - 12/3/2007 00:00 Operations Summary Lay 8 bbl balanced cement plug at 6,245 ". Pull 6 stands and perform hesitation squeeze. WOC. TOOH for drillout BH TIH with 4 1/8" bit and drill out BHA. Wash from 5,672' - 5,948'. • • Chevron Chevron - Alaska Daily Operations Summary Well Name Field Name API /UWI Lease/Serial Orig KB Elev (ftKB) Water Depth (ft) M -17 McArthur River 507332055200 TRADING BAY UNIT 79.2 185.00 Daily Operations 12/3/2007 00:00 - 12/4/2007 00:00 Operations Summary Drill out squeezed perfs to 6250'. Attempt to t= .t to 1250 psi w/o success. TOOH. TIH with 4 1/8" bit and scraper to 6230'. 12/4/2007 00:00 - 12/5/2007 00:00 Operations Summary TOOH. MU EZSV on DP setting tool and TIH. Se etainer @ 6209. No indications of good set. TOOH. EZSV not on running tool. TIH adn attempt to inject below retainer....Pressures up...cant pump thr gh retainer. 12/5/2007 00:00 - 12/6/2007 00:00 Operations Summary Continue to attempt to establish injection below retainer.. 'o success. TOOH. TIH with drill out assy. Drill out retainer and test perfs to 1250 psi ok. Continue to drill out cement, CIBP, and clean out to 7435. 12/6/2007 00:00 - 12/7/2007 00:00 Operations Summary Make bit and scraper run to PBTD. Displace to FIW. TOOH. IH with polish mill and polish PBR. TOOH laying down DP. 12/7/2007 00:00 - 12/8/2007 00:00 Operations Summary Finish laying down 3 1/2" DP. Run completion and 3 1/2" tubing. P RSED 12/8/2007 00:00 - 12/9/2007 00:0 Operations Summary ' /' % j Finish running 3 1/2" completion. Land hanger. Start ND BOP's b C , . � �C / __ 12/9/2007 00:00 - 12/10/2007 00:00 Operations Summary Finish ND BOP. Land tree and test 250/5000 OK. Prepare equipment for orage and rig move. 12/10/2007 00:00 - 12/11 /2007 00:00 Operations Summary Continue to prepare rig for skidding operations. 12/11/2007 00:00 - 12/12/2007 00:00 Operations Summary Finish rigging down service lines. Skid rig to waterflood. 12/12/2007 00:00 - 12/13/2007 00:00 Operations Summary Work in pits to prepare for CT operations. Continue to prepare rig for shut down. 12/13/2007 00:00 - 12/14/2007 00:00 Operations Summary Continue to clean up and prepare rig fro CT operations. RU ELU and attempt to RIH and co - ct SCMT log. Couldnt get past 2500'. POOH for weight bar. 12/14/2007 00:00 - 12/15/2007 00:00 Operations Summary Finish running cement bond log. RDMO ELU. Send crews in for safety meeting. 12/15/2007 00:00 - 12/16/2007 00:00 Operations Summary Rig clean up and maintenance 12/16/2007 00:00 - 12/17/2007 00:00 Operations Summary Rig clean up and maintenance 12/17/2007 00:00 - 12/18/2007 00:00 Operations Summary Rig clean up and maintenance 12/18/2007 00:00 - 12/19/2007 00:00 Operations Summary Continue rig maintenance. Start recieving CTU components. 12/19/2007 00:00 - 12/20/2007 00:00 Operations Summary Finish RU CTU. Test BOPs and lubricator 250/3000. 12/20/2007 00:00 - 12/21/2007 00:00 Operations Summary Finish RU CTU. RIH and reverse out water with N2. POOH. RU ELU and RIH with perf guns. . • Chevron Chevron - Alaska %. Daily Operations Summary Well Name Field Name API /UWI Lease /Serial Orig KB Elev (ftKB) Water Depth (ft) M -17 McArthur River 507332055200 TRADING BAY UNIT 79.2 185.00 Daily Operations 12/21/2007 00:00 - 12/22/2007 00:00 Operations Summary Perforate 7456 -7470 (D -17 Sand). Obse PBU. RDMO CTU and ELU. 12/22/2007 00:00 - 12/23/2007 00:00 Operations Summary Rig maintenance and Demob personnel. 12/26/2007 00:00 - 12/27/2007 00:00 Operations Summary "` RU SLU and tag fill at 7540. Att to identify fluid ley; with bailer w/o success. 12/27/2007 00:00 - 12/28/2007 00:00 r __ Operations Summary ` _ RU ELU and run gradient tool. Locate FL and prep to r- •erf the D -17. 12/28/2007 00:00 - 12/29/2007 00:00 Operations Summary Reperforate D -17 7456 -7470. Tools stuck after the shots. • - ssure slowly increasing. 12/29/2007 00:00 - 12/30/2007 00:00 Operations Summary Continue to work stuck tools. Ultimately pull out of rope socket. '00H with Eline. 12/30/2007 00:00 - 12/31/2007 00:00 Operations Summary Flow test D -17 sand. 1/17/2008 00:00 - 1/18/2008 00:00 Operations Summary Ran 2.75" GR to 7438' and temp press tool to 7300' 1/18/2008 00:00 -1 /19/2008 00:00 Operations Summary Cont temp /press survey 1/24/2008 00:00 - 1/25/2008 00:00 Operations Summary Ran Posi -Set plug and set down high at 7376'. POOH w/ plug. 1/25/2008 00:00 - 1/26/2008 00:00 Operations Summary No Operations. 2/2/2008 05:30 - 2/3/2008 00:00 Operations Summary Ran 2 -1/4" bail and 2.78" GR to 7444'. Ran 3 -1/2" X -line to identify nipple. 2/3/2008 00:00 - 2/4/2008 00:00 Operations Summary Ran 2 -1/2" bull nose as a feeler and set down high at 7377'. POOH. 2/4/2008 00:00 - 2/5/2008 00:00 Operations Summary Site visit by Schlumberger coil and cement hands. 2/5/2008 00:00 - 2/6/2008 00:00 Operations Summary Clear deck space for coil and start unloading coil tubing unit from boat. 2/6/2008 00:00 - 2/7/2008 00:00 Operations Summary Cont to rig up coil tubing unit. 2/7/2008 00:00 - 2/8/2008 00:00 Operations Summary Cont coil rig up and pressure test bops and send to state. 2/8/2008 00:00 - 2/9/2008 00:00 Operations Summary RIH w /coil tubing and attempt to wash fill at 7296' ctm. Could not wash fill. POOH w /coil. Ran 2 -1/4" slickline bailer and - il on obstruction at 7374'. 2/9/2008 00:00 - 2/10/2008 00:00 Operations Summary POOH w /slickline and rig down. Change out stripper rubber on coil injector. Chevron • Chevron - Alaska Daily Operations Summary Well Name Field Name API /UWI Lease/Serial Ong KB Elev (ftKB) Water Depth (ft) M -17 McArthur River 507332055200 TRADING BAY UNIT 79.2 185.00 Daily Operations 2/10/2008 00:00 - 2/11/2008 00:00 Operations Summary ' ■ Clean out fill with coil tubing from 7338' coil tubing - asurement to 7399'. 2/11/2008 00:00 - 2/12/2008 00:00 fe Operations Summary i Ran 2 -1/2" bull nose and tag fill at 7430.5. Set posi -set p • at 7423'. 2/12/2008 00:00 - 2/13/2008 00:00 Operations Summary Dump bail 15 of cement on plug. 2/13/2008 00:00 - 2/14/2008 00:00 Operations Summary Tag top of cement at 7405'. RIH w /coil and lay in 18 bbis 6% KCL, 1: atio. Blow well dry from 7100' w /N2. Rig down coil tubing. 2/14/2008 00:00 - 2/15/2008 00:00 Operations Summary Perf w/2 -1/2" PJ Omega, 60 deg, 6spf from 7296' to 7308' with 305 psi on •ing. Monitor well. Perforate w /same type gun from 7361'- 7391'. 2/15/2008 00:00 - 2/16/2008 00:00 Operations Summary Ran Schlumberger press /temp log and find fluid level at 6175. Monitor well. 2/16/2008 00:00 - 2/17/2008 00:00 Operations Summary Perf from 7361' to 7381' w/2.125" power spiral, 5 spf, 45 deg phase. Perf w /same from 98' to 7308'. Rig down a -line 2/19/2008 00:00 - 2/20/2008 00:00 Operations Summary Perf w/2.5" power spiral, 5 spf from 5832' to 5856'. Pressure went from 470 psi to 832 psi. F . ing 3.3 MMSCFD at 795 psi. • . Chevron Steelhead M-17 1 %. Mud Density -v- Depth %. 0 , —0—M -17 Mud Density 14.*'%%.‘44....'%% 1000 2000 - - 3000 r � r - A T400 1 J L L 4 CA 5 � F 5000 6000 i - - r r - 7000 L 1 - L 8000 I I I I I I 8.8 8.9 9.0 9.1 9.2 9.3 9.4 9.5 9.6 Mud Density (ppg) M -17 MW vs D.xls 3/9/2008/ 2:58 PM 111 • Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant 909 W. 9th Avenue _.... ..... ..„, „....„ ... Anchorage, AK 99501 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE March 7, 2008 To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL ,i;,-;:va:-&04EIT '',-:::ak::::-",:f:,,•; mgar:',Nalsr 1::i 'i' ' !::-,,- -witaAmt .,: !1:i ,. • ,,.avAt ::,,p,pg$04 , RW44 , `' "g,..1 - tt-Wil; ,, m0 , 41 ,,=M1 .;: '''' •':‘,•iN Tp.>,, ,,, :-..,,,, ,sege LWD FORMATION EVALUATION - MAGNETIC RESONANCE CHANNEL LAS, PDF, TBU M-17 LEVEL AND ECHO DATA REPROCESSING 2" 21-Nov-07 1440-5680 1 1 1 ZIP Please acknowledge receipt by signing and returning one copy of this traiistrttal Ori 263 7828. Received By: 7) 1 ii "._._____-------- Date: • ,.,---- :-• .„, • 1 Gary A. Orr Chevron North America Chevron Reservoir Engineer Exploration and Production MidContinent/Alaska SBU 909 West 9 Avenue B P.O. Box 196247 Anchorage, 6247 Tel ef 907 7 7 263 78600 00 Fax 907 263 7847 Email orrga @chevron.com February 26, 2008 Mr. John Norman, Commissioner Alaska Oil and Gas Conservation Commission RECEIVE(' 333 W. 7 Avenue, Suite 100 Anchorage, AK 99501 -3539 F Fib r; 2008 Form 10 -421 Alaska) 00 & Gas Cons. Cornmiss or= For Well M -17, McArthur River Field Anchorage Dear Commissioner Norman: Attached is Form 10 -421 "Gas Well Open Flow Potential Test Report" for the newly completed Well M -17 on the Steelhead Platform. Please contact Gary Orr at 263 -7800 if you have any questions. Sinc rely, Gary • rr Reserf.it Engineer Cc: Dave Whitacre Attachments MidContinent /Alaska SBU /Chevron North America Exploration and Production www.chevron.com t STATE OF ALASKA • ALI OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. Test: U Initial U Annual U Special 1b. Type Test: U Stabilized U Non Stabilized U Multipoint ❑ Constant Time ❑ Isochronal ❑ Other 2. Operator Name: 5. Date Completed: 11. Permit to Drill Number: Union Oil Company of California 2/19/2008 207 -120 3. Address: 6. Date TD Reached: 12. API Number: PO Box 196247, Anchorage, AK 99519 November 16, 2007 50- 733 - 20552 -00 . 4a. Location of Well (Governmental Section): 7. KB Elevation (ft): 13. Well Name and Number: Surface: 1052' FNL 455' FWL, SEC 33 T9N, R13W, SM ' 160' • Steelhead M -17 . Top of Productive Horizon: 8. Plug Back Depth(MD +TVD): 14. Field /Pool(s): 3809' FNL, 204' FEL, Sec 32, T9N, R13W, SM 7405 -6158' McArthur River Field Total Depth: 9. Total Depth (MD + TVD): Middle Kenia Gas Pool 4712' FNL, 321' FEL, Sec 32, T9N, R13W, SM 7670'/6380' 4b. Location of Well (State Base Plane Coordinates): 10. Land Use Permit: 15. Property Designation: Surface: x- 214070 ' y- 2499450 • Zone- 4 ADL- 17594, ADL 18730 TPI: x- 213429 y- 2496699 Zone- 4 16. Type of Completion (Describe): Total Depth: x- 213204 y- 2495811 Zone- 4 perforated casing 17. Casing Size Weight per foot, Ib. I.D. in inches Set at ft. 19. Perforations: From To 5" 18 4.276 7637 5832 -5856' 18. Tubing Size Weight per foot, Ib. I.D. in inches Set at ft. 7296 -7308' 3-1/2" 9.2 2.992 5472' 7361 -7391' 20. Packer set at ft: 21. GOR cf /bbl: 22. API Liquid Hydrocardbons: 23. Specific Gravity Flowing Fluid (G): 5472' NA NA • NA 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: 24d. Barometric Pressure (Pa): El Tubing ❑ Casing 102 F° • 951 psia @ Datum 4818 TVDSS 14.7 psia 25. Length of Flow Channel (L): Vertical Depth (H): Gg: % CO % N2: % H Prover: Meter Run: Taps: NA NA 0.57 ' 0 0 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line )( Orifice psig Hw F psig F psig F Hr. Size (in.) Size (in.) 1. X 839 69 0 NA 0 2. X 808 70 0 NA 2 3. X 793 73 0 NA 2 4. X 770 75 0 NA 2 5. X 744 76.9 0 NA 2 Basic Coefficient Flow Temp. Super Comp. No. (24 -Hour) hwPm Pressure Factor Gravity Factor Factor Rate of Flow Fb or Fp Pm Ft Fg Q Mcfd Fpv 1. 0 2 3120 3 3980 4 5020 5 5990 • Temperature for Separator for Flowing No. Pr Tr z Gas Fluid T Gg G 1. 562 • 1.638484 0.899 2. 1.37454982 562 1.638484 0.899 3. 1.349039616 562 1.638484 0.907 Critical Pressure 666.4 4. 1.31002401 562 _ 1.638484 0.911 Critical Temperature 343 5. 1.266506603 562 1.638484 0.913 Form 10 -421 Revised 1/2004 09v15 f • • I c .1 - . ERSE SIDE k.. ; Submit in Duplicate t, Pc 853.7 pct 728803.69 1 950.8 p{ 904020.64 No. Pt pt2 Pct -Pt2 Pw Pw Pc Ps Ps Pf -Ps 1. 2. 823 677329 51474.69 93 8649 720154.69 916 839056 64965 3. 808 652864 75939.69 91 8281 k 720522.69 899 808201 95820 4. 785 616225 112578.69 88 7744 721059.69 873 762129 141892 5. 759 576081 152722.69 85 7225 721578.69 844 712336 191685 25. AOF (Mcfd) 15,240 n 0.60209 Remarks: I hereby certif ' that the fore oing is true and correct to the best of my knowledge. � � Signed A A_ 4 /J ` � � Title Petroleum Engineer Date 2 /22 /2008 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/ hw Pm 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 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Tyler, Steve L [tylersl @chevron.com] Sent: Monday, February 18, 2008 4:17 PM To: Maunder, Thomas E (DOA); Rose, Jim - Contractor Cc: Walsh, Chantal [Petrotechnical] Subject: RE: Steelhead M -17, PTD 207 -120 Tom Please be advised on M -17 grass root gas well, we have performed the following: • CT jetted well dry. • Perf D -17 sands No Joy • Re -pert D -17 sands Stuck guns No Joy • CT CO of fill. • Isolated D -17 sands. • CT jetted well dry. • Perf D -16 sands No Joy • Re -Perf D -16 sands Still No Joy Currently planning on moving up the hole and perforating the D -3 sands tomorrow. Hoping to find Joy or gas. From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, January 10, 2008 12:18 PM To: Rose, Jim - Contractor Cc: Tyler, Steve L; Walsh, Chantal [Petrotechnical] Subject: RE: Steelhead M -17, PTD 207 -120 Jim, et al, I confirm that all the well activities may be reported on the 407. It is not necessary to file an interim 404. Tom Maunder, PE AOGCC From: Rose, Jim - Contractor [mailto:RoseJi @chevron.com] Sent: Thursday, January 10, 2008 12:00 PM To: Maunder, Thomas E (DOA) Cc: Tyler, Steve L; Walsh, Chantal [ Petrotechnical] Subject: Steelhead M -17, PTD 207 -120 Tom To confirm our conversation, it is not necessary to file a 10-404 to close out the filed 10-403 on the subject well. The perforating was covered under the 10-401 (APTD) and will be reported on the 10-407 when the well is completed. Thanks, Jim cA � cow Co w 7/1/2008 Chevron Fr•isco Castro Chevron North A•ce Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 440. Tele: 907 263 7889 Fax: 907 263 7828 E-mail: fcbn@chevron.com - --- January 2, 2008 To: AOGCC Mahnken, Christine R 333 W. 7t' Ste#100 - Anchorage, AK 99501 DATA TRANSMITTAL Enclosed is the Final Mud Report for Steelhead M-17. 1z' ,.",77 .47 - L O G T Y P E WELL P '1%03 t.00,44E,19.N,TfpRwsn , LINE HLM ,7,4 DML, LAS, M-17 FINAL WELL DATA 2" 5-Dec-07 485 - 7670 1 1 1 PDF tSt Please acknowledge receipt by signing and returning one copy of tbk... relS9.'ttai k. Xi) 907 263 7828. Received By: / Date: - • 3 • Chevron Frisco Castro Chevron North Mirka Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7844 1%111 Fax: 907 263 7828 E-mail: fcbn@chevron.com December 18, 2007 - . .;, To: AOGCC Mahnken, Christine R 333 W. 7 Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL NAME , 'WELL - 1% 1 TYPE SALE LOG DATE LINE MULTIPLE PROPAGATION OCTOBER RESISTIVITY 26, 2007- 1 1 M-17 COMPENSATED 2" NOVEMBER NEUTRON POROSITY 17 2007 COMPENSATED BULK , DENSITY GAMMA RAY 6o - -do315 -a /00 14- ISt / Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: f Date: • Page 1 of 1 • Maunder, Thomas E (DOA) From: Walsh, Chantal [Petrotechnical] [WalshC @chevron.com] Sent: Wednesday, December 19, 2007 11:41 AM To: Maunder, Thomas E (DOA) Cc: Buster, Larry W; Rose, Jim - Contractor Subject: TBU M -17 (207 -120) Tom, You requested information on the casing testing for the M -17 well: 9 -5/8" casing was tested to 2500 psi on 11/6/07. 7" casing was tested to 3500 psi on 11/13/07. 5" liner, after the isolation perfs were squeezed off, was tested to 1250 psi on 12/5/07. Chantal 1/10 /2008 • • S TH .... EDI , � � r a n SARAH PALIN, GOVERNOR GOVE OR ALASKA. OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Larry Buster Drilling Engineering Manager UNOCAL PO Box 196247 Anchorage, AK 99519 Re: McArthur River Field, Middle Kenai Gas Pool, M -17 Sundry Number: 307 -378 Dear Mr. Buster: 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, o., . No - DATED this 'day of December, 2007 Encl. 1 N. M.rCfVCU' ,- ',/ ) /.. 06 17 ' 1 "i STATE OF ALASKA • b 1 8 2007 ALASKA OIL AND GAS CONSERVATION COMMISSI APPLICATION FOR SUNDRY APPROVALt An Oil & Gas Cons. Commission 20 AAC 25.280 A#I"hra 8 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 0 ' Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 Exploratory ❑ 207 -120 - 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 733 - 20552 -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 0 Steel head M - 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ,rr. qr /4 -44.4 ADL- 17594, ADL 18730 79.2' McArthur River Field, Gra a -Sal s AtS /2. /ff o7 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): 7670' 6379' 7637' 650' n/a n/a Casing Length Size MD TVD Burst Collapse Structural 485' 28" 485' 485' Conductor Surface 895' 13 -3/8" 895' 895' 5020 psi 2260 psi Intermediate 1430' 9 -5/8" 1430' 1404' 5750 psi 3090 psi Production 5700' 7" 5700' 4669' 7240 psi 5410 psi Liner 2165' 5" 7637' 6350' 10140 psi 10500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): see attached procedure 6054' (contingency)- 6205'tvd 3 -1/2" L -80 / 9.2# 5472' Packers and SSSV Type: Baker ZXP Flex III Hanger pkr / Packers and SSSV MD (ft): Baker TE5 SCSSV 5472' / 439' 13. Attachments: Description Summary of Proposal le 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 151 Service ❑ 15. Estimated Date for 12/19/2007 16. Well Status after proposed work: Commencing Operations: Oil ❑ Gas 0 Plugged ❑ Abandoned ❑ 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ p WDSPL ❑ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Larry Buster - 263 -7853 Printed Name Larry J� — ...,, Title Drilling Engineering Manager Signature — I ho, 263 -7853 Date 1412442007 J 1t I1'1lei COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 604 ' 348 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: v S \ `� '\ S \ CkS * Se_ Subsequent Form Required: `�p i RBDMS 8F.' DFr 9 2007 APPROVED BY Approved by: ' / COMMISSIONER THE COMMISSION Date: /•-•! kg Form 10-403 Revised 06/2006 " , -' e Submit in Duplicate • • Chevron -- 111111 Steelhead Platform Well M -17 C ompletion Procedure M -17 Completion Procedure 1. MU RU 1 -3/4" Coil Tubing and Nitrogen Units. 2. Test BOP's, lubrication and lines to 250 / 3000 psi. 3. RIH to 7519. 4. Displace wellbore with nitrogen. 5. Pump 6% KCL cushion. 6. POOH. RD CTU 7. MIRU Eline, lubricator, and grease head. Test lubricator to 3000 psi. 8. RIH with CCL and 2-1/2" PowerJet Omega perf guns with 6 spf. 9. Tie in. 10. Perforate D17 sands (7456' - 7470'md) 11. POOH. RD Eline. 12. Turn well over to production. Contingency plan (If D17 sands are watered out): - 1. MURU Eline. 2. RIH and set Posi -set Bridge plug above the D17 perfs. 3. Dump bail approximately 15' of cement on plug. 4. MU RU 1 -3/4" Coil Tubing and Nitrogen Units. 5. Test BOP's, lubrication and lines to 250 / 3000 psi. 6. RIH. 7. Displace wellbore with nitrogen. 8. Pump 6% KCL cushion. 9. POOH. RD CTU. 10.MIRU Eline, lubricator, and grease head. Test lubricator to 3000 psi. 11. RIH with CCL and 2-1/2" PowerJet Omega perf guns with 6 spf. 12.Tie in. 13. Perforate D16C sands (7361' - 7391'md) 14. POOH. Reload guns. RIH with 2-1/2" PJ Omega guns, 6spf. 15.Tie in. 16. Perforate D16A Sands (7296' - 7308'md) 17. POOH. RD Eline. 18.Turn well over to production. • 12/18/2007 Page 1 of 1 Chevron • •teelhead Platform %. Well M -17 %. As Built 12/05/07 CASING AND TUBING DETAIL RKB to TBG Head = 78'75.00' SIZE WT GRADE CONN MIN ID TOP BTM 28" Conductor (MDrkb) 28" Structural 27" Surface 485' • 13 -3/8" 68 L -80 BTC 12.415 Surface 895' ECP stage Collar 9 -5/8" 40 L -80 BTC 8.679 Surface 1430' ' III i 13 -3/8" in 17' " Hole 7" 26 L -80 BTC -M 6.276 Surface 5700' 5" liner 18 L -80 H513 4.194* 5472' 7637' Tubing 3 -1/2" 9.2 L -80 IBTM 2.992 Surface 5472' II Est TOC @ 920' The 5 ", 18 ppf, FJ liner has an ID of 4.276" and a drift of 4.155 ". The H513 connection has a 4.194" machined pin ID. S 9 -5/8" in 12' "Hole The Baker ZXP Flex III hanger packer assembly has a TKC x H513 X over with a 4.180" machined ID. This represents the minimum ID in the5" liner. Perforation Detail MD Zone Density (SPF) Notes 5782 -5788 6 Sqzd, Ref SCMT Log 11/22/07 6234 -6240 6 Sqzd, Ref SCMT Log 11/22/07 Profile Nipple Miscellaneous Equipment Informtion 7" Casing in 8''A" Hole Item Depth OD ID Notes 13 3/8 x 28" ECP Stage Collar 454 Cem'd to Surf 9 5/8 x 13 3/8 ECP Stage Collar 849 Attempt to Cemt to ML Baker TE5 SCSSV 439 5.370 2.813 X Tubing Retrievable GLM 4, SFO-2, R -2 VLV, RK 1807 5.968 2.867 GLM 3, SFO-2, R -2 VLV, RK 3738 5.968 2.867 GLM 2, SFO-2, R -2 VLV, RK 4784 5.968 2.867 GLM 1, SFO-2 (.250 Orifice) 5369 5.968 2.867 X Profile Nipple 5426 3.973 2.813 X 10' Locator Seal Assy 5472 5.250 4.278 Cementing Information Description Volume Dens Yield Notes (bbls) (ppg) (ft3 /sx) Top of Primary 13 3/8 Stage 1 147 15.8 1.16 G GasBlok Cement is 7034" 13 3/8 Stage 2 76 L, 188 T 15.8 1.17 62 bbls Cement to Surf G GasBok and G CaCI 5" Liner in 6 1/8" Hole 9 5/8 Stage 1 57 15.8 1.16 G GasBlok ' t 9 5/8 Stage 2 32 15.8 1.17 G GasBlok, Cmt to surf?!? 7" Production 143 12.0 2.49 G LiteCrete 5" Liner Primary 49.5 15.8 1.2 G LXT, Partial to complete losses, packed off. TOC @ 7034' per SCMT 5" Circulation Sqeeze 16.5 15.8 1.2 G LXT, Partial to complete 6240 -5782 losses. MAX HOLE ANGLE = 56.4° @ Tangent 2,796' MD Well Detail DRAWN BY: JAR 12/05/07 Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, December 18, 2007 5:03 PM To: 'Walsh, Chantal [Petrotechnical)' Cc: Larry Buster Subject: TBU M -17 (207 -120) Chantal, Confirming our conversation, Commissioner Norman has given oral approval for Unocal to proceed with the completion of TBU M -17 as outlined in your returned to you tomorrow. The signed document will be etu ed t sundry application. rY 9 Y Call or message with any questions. Tom Maunder, PE AOGCC 12/19/2007 1 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, November 27, 2007 9:34 AM To: 'Rose, Jim - Contractor' Subject: RE: M -17 (207 -120) plan forward Good luck. From: Rose, Jim - Contractor [mailto:RoseJi @chevron.com] Sent: Tuesday, November 27, 2007 9:28 AM To: Maunder, Thomas E (DOA) Subject: M -17 plan forward Tom, As you know, we didnt get much of a cement job on the M -17 liner. The basic plan forward follows: 1. Set CIBP below perfs, shoot holes in the 5" liner at 6234 -6240 (which is below the D6....the lower pay was effectively covered with cement during the primary attempt). Set retainer above perfs. The 7" shoe is at 5710. (perfs shot this am. Setting retainer at present). 2. Attempt a circulation cement job behind the liner and past the liner hanger (5472). Depending on results, we will set another isolation packer if the 1st one cant be made to set and test. 3. Drill out the perfs, test, and squeeze if necessary. Then run completion. Call with any concerns or comments. 263 -7637 Jim • ill 11/27/2007 Chevron Activity Page 1 of Z Maunder, Thomas E (DOA) From: Brandenburg, Tim C [brandenburgt @chevron.com] Sent: Monday, November 26, 2007 6:48 PM To: Maunder, Thomas E (DOA) Cc: Rose, Jim - Contractor Subject: RE: Chevron Activity Tom, We will send a copy of the plan. We did fight pack off problem and the well unloaded a considerable amount of coal during the clean out as well as after circulating off the top of the liner after the cement job. We did not note losses during the initial placement of the cement but did at the very end of the displacement. The Bond log on the cement that is in place is outstanding. You are right, the fact that the ZXP did not set is a good thing (never thought I would say that) and it is currently factoring into our plans for the circulating cement job. Tim From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, November 26, 2007 3:54 PM To: Brandenburg, Tim C Subject: RE: Chevron Activity a g�_ Hi Tim, Keep us informed on the remedial work on M -17. When the plan is determined, I'd appreciate a copy. Cement did not come up very far. Was lost circulation experienced? Given that the TOC is a long way from where it was desired, it is probably a good thing that the ZXP did not set. Might have a chance to break circulation. Good luck. Tom Maunder, PE AOGCC From: Brandenburg, C mailto:br n n a de bur t chevron. 9, E g @ com] Sent: Monday, November 26, 2007 3:49 PM To: Maunder, Thomas E (DOA) Subject: Chevron Activity «CVX Wellwork 07.xls» Tom, Hope you had a good Thanksgiving. Please find that attached summary of operations. Please note that the cement job on M -17 production liner did not achieve the desired coverage and the ZXP liner top packer did not set. Jim Rose and the team are working a plan to perforate the 5" liner and perform a circulating cement job and then to fully set the ZXP or install another on top of it. Tim 11/27/2007 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, October 26, 2007 6:11 PM To: Rose, Jim - Contractor Cc: Regg, James B (DOA) Subject: RE: M -17 Jim, I would concur with that value. Tom Maunder, PE AOGCC ao — ` a10 Original Message From: Rose, Jim - Contractor [mailto:RoseJi @chevron.com] Sent: Fri 10/26/2007 3:57 PM To: Maunder, Thomas E (DOA) Subject: RE: M -17 • Tom, I would propose a 2000 psi test for the 9 5/8 rams only and a 4000 psi test for the remainder of the stack. Please advise. Thanks, Jim From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, October 26, 2007 3:11 PM To: Rose, Jim - Contractor Cc: Harness, Evan; Jim Regg Subject: RE: M -17 Jim, Your proposal to initially equip the BOP with DP rams and 9 -5/8" casing rams has merit. Both sets of rams can be installed, tested and if necessary repaired prior to exiting the 13 -3/8" casing rather than conducting installation and testing with 12 -1/4" open hole. Installing the casing rams prior to drillout should allow a smooth operational flow from drilling to casing and will eliminate exposure with open hole due to prolonged delays possible if difficulties were encountered testing the rams. The calculated surface pressure for the actual gas sand penetration (deeper than the 9 -5/8" shoe) is about 1650 psi. According to the regulations, 2 rams (blind and pipe) and an annular are required to for such pressure. The casing rams should be tested when installed. In the application, a 4000 psi BOP test is planned. It is your option to propose to test the casing rams to a lower value if desired. Please respond if that is desired. Employing casing rams while drilling is for the 12 -1/4" hole section only. A copy of this message should be available at the rig. Call or message with any questions. Good luck with the operations. Tom Maunder, PE 1 • • AOGCC From: Rose, Jim - Contractor [mailto:RoseJi @chevron.com] Sent: Wednesday, October 24, 2007 1:27 PM To: Maunder, Thomas E (DOA) Subject: RE: M -17 On Steelhead, we just monitor them. We do not bleed them unless there is valve to repair or something. Jim From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, October 24, 2007 1:12 PM To: Rose, Jim - Contractor Subject: RE: M -17 Curious what pressures might exist out there and if there is any active management (bleeding). Tom From: Rose, Jim - Contractor [mailto:RoseJi @chevron.com] Sent: Monday, October 22, 2007 10:26 AM To: Maunder, Thomas E (DOA) Subject: RE: M -17 Tom To the best of my knowledge, the majority of the drive pipe x surface pipe annuli have about 150 psi on them. Some of the surface x intermediate annuli also have a little bit of pressure on them. I dont have the exact pressures but they are monitored and I can get that data from the production dept if you like. What are you thinking? Jim From: Maunder, Thomas E (DOA) [mailto:tom.maunder @ alaska.gov] Sent: Monday, October 22, 2007 8:55 AM To: Rose, Jim - Contractor Subject: RE: M -17 2 • Jim, Is there any information regarding pressures in the casing annuli of wells around the proposed path of M -17? So far as I am aware, no issues have been reported to the Commission. Not much recent grass roots drilling out there, M -12 (late 2001) appears to be most recent well preceded by M -09 (1996) and M -16 (1997). Tom Maunder, PE AOGCC From: Rose, Jim - Contractor [mailto:RoseJi @chevron.com] Sent: Tuesday, October 16, 2007 1:19 PM To: Maunder, Thomas E (DOA) Subject: M -17 Tom, M -17 will likely spud in the next week or so. I have a question... We were approved for a 250/4000 bop test though we are rigging up in a 5M configuration. when we nipple up the bops, can i dress the lower ram cavity with the 9 5/8 casing rams? We are only drilling from 850 -1420 and then setting 9 5/8. Thanks Jim 3 Page 1 of 1 Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Friday, October 19, 2007 11:57 AM To: Maunder, Thomas E (DOA) Subject: RE: M -17 a O - So the stack would be configured Annular /Pipe Rams /Blind Rams /Casing Rams? Chevron should provide data confirming there are no annular pressure problems (or does "unaware of" mean doesn't exist ?). Interestingly, we have no SCP rules in place for any of the TBU fields, but the regulations require the wellhead to be configured to monitor all casing annuli [25.200(c)], and allow the Commission to require tests to determine formation, tubing, casing, or other pressures [25.534(a)(2)]. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907 - 793 -1236 fax: 907 - 276 -7542 From: Maunder, Thomas E (DOA) [mai(to:tom.maunder @alaska.gov] Sent: Friday, October 19, 2007 11:17 AM To: aogcc_prudhoe _bay @admin.state.ak.us Subject: FW: M -17 All, I wanted to get some input regarding this request. Casing point requirements were set due to the blowout of some 20 years ago. From what I see in the recent well files there haven't been problems encountered drilling wells. I am also not aware of any annular pressure problems. Thoughts and opinion will be appreciated. I understand the well could spud mid next week putting the stack NU about a week later. Thanks, Tom From: Rose, Jim - Contractor [mailto:Rose]( @chevron.com] Sent: Tuesday, October 16, 2007 1:19 PM To: Maunder, Thomas E (DOA) Subject: M -17 Tom, M -17 will likely spud in the next week or so. I have a question... We were approved for a 250/4000 bop test though we are rigging up in a 5M configuration_ when we nipple up the bops, can i dress the lower ram cavity with the 9 5/8 casing rams? We are only drilling from 850 -1420 and then setting 9 5/8. Thanks Jim 10/29/2007 • • scmiTE o V G O ERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 SARAH PAULA CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 Re: Mc Arthur River Field, Middle Kenai Gas Pool, Steelhead M -17 UNOCAL Permit No: 207 -120 Surface Location: 1052' FNL, 455' FWL, SEC. 33, T9N, R13W, SM Bottomhole Location: 4688' FNL, 342' FEL, SEC. 32, T9N, R13W, SM Dear Mr. Brandenburg: Enclosed is the approved application for permit to drill 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). Sin terely, Q4( / John K. Norman g U Chairman DATED this -day of September, 2007 cc: Department of Fish & Game, Habitat Section w/o end. Department of Environmental Conservation w/o end. RECEIVED STATE OF ALASKA � ALAS�OIL AND GAS CONSERVATION COMAlI. ION Ailliad\sa s P Q 5 200 PERMIT TO DRILL ti Gas Cons. Cammissmrt" 20 AAC 25.005 1a. Type of Work: lb. Current Well Class: Exploratory ❑ Development Oil 111 1c. Specify if well is proposed for: Anchorage Drill i0 Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket i0 Single Well ❑ 11. Well Name and Number: Union Oil Company of California Bond No. 086S103515406BCM SteelheadM -17 3. Address: 6. Proposed Depth: 12. Field /Pool(s): PO Box 196247, Anchorage, AK 99519 MD: 7,630' TVD: 6,343' McArthur River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Grayling Gas Sands Surface: 1052' FNL 455' FWL, SEC 33 T9N, R13W, SM ADL- 17594, 18730 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2988' FNL, 43' FEL, Sec 32, T9N R13W SM 9/99/2007 Total Depth: 9. Acres in Property: 14. Distance to Nearest r 4688' FNL, 342' FEL, Sec 32, T9N, R13W, SM 3840 Property: 10090' to unit B 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Ne ell Surface: x- 214070 » y- 2499450 ' Zot 4 (Height above GL): 160 AMSL feet Within Pool: /Yl /`f ,4 ►-" 16. Deviated wells: Kickoff depth: 800 feet ' 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) !,T ( 3 ,07 Maximum Hole Angle: 58 degrees , Downhole: 3067 , Surface: 1654 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) Cond 28 -32 1/2 - 1" WT X -56 Weld 402 0 0 480 480 Driven 17 1/2" 13 3/8" 68 L -80 BTC 850 0 0 - 850 . 850 2429 ft3 in 2 stages 12 1/4" 9 5/8" 40 L -80 BTC 1420 0 0 . 1420 1400 627 ft3 in 2 stages 8 1/2" 7" 26 L -80 BTCM 5721 0 0 5721 4690 908 ft3 in 1 stage 6 1/8" 5" 18 L -80 . 1 - 1yd513 2109 5521 4517 7630 6343 220 ft3 in 1 stage 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 ND (ft): Junk (measured): 1 Casing Length Size Cement Volume MD TVD Conductor /Structural 420.00 28 -32 Driven 480 480 Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketch 12 Drilling Program El Time v. Depth Plot Ell Shallow Hazard Analysis ❑ Property Plat 0 Diverter Sketch 151 Seabed Report ❑ Drilling Fluid Program ial 20 MC 25.050 requirements 111 21. Verbal Approval: Commission Representative: Date 8/30/2007 22. I hereby certify that the foregoing is true and correct. correct. Contact Jim Rose, 907 - 263 -7637 Printed Name 7 -tt 7 C j,iy > -L,, Title �2`z LL c /1/1 -4- - k ; Signature r� Phone ( o ) .. 2?-7 - 3_._ - .7.65---9._ Date -` j "3 Commission Use Only — Permit to Drill API Number Permit Appr val 'See cover letter for other Number: Z d7 � 1 2Z ) 50- 755 ■ 21)...S75 (Date: � •�� requirements. Conditions of approval : If box is checked, well may not be u explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:[ Other: ( \ ` 1 Samples req'd: Yes❑ No[✓ ' Mud log req'd: Yes❑ No �SN Y , c _ L �. kcvt.�C H measures: Yesg No❑ Directional s req'd: Yes No❑ P1 =, A \vi,.5\1 k l s ' / t 6 ` ..lQ r ‘■ ckc p k_ , 40 3-S,CSs' , ��� APPROVED BY THE COMMISSION DATE: Z6"b �itt.e2-11.-4„,,,.„ , COMMISSIONER Form 10-401 Revised 12/2005 r - 4 f I [ �, A L Submit in Dup e , 3 [�r�l t� . 01 • • Chevron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, , AK AK 99519 -6247 Tel 907 263 7657 Fax 907 263 78888 4 Email brandenburgt @chevron.com RECEIVED August 30, 2007 SEP 0 5 2007 Alaska Oil & Gas Cams. Commission Commissioner Anchorage Alaska Oil & Gas Conservation Commission 333 W. 7 Avenue Anchorage, Alaska 99501 Re: Steelhead M -17 Dear Commissioner, Enclosed for review and approval is the application for the Permit to Drill the Steelhead M -17 well. Drilling operations are expected to commence approximately Sept 22, 2007 depending on the progress of other ongoing projects. According to the Commissions' letter dated May 11, 2005, a spacing exemption is not required to drill or operate this well. In accordance with 20 AAC 25.005 (c)(4)(A -C). (A) MASP calculations are attached for review. (B) The Grayling Gas Sands are potentially gas bearing throughout the section. Potential target reservoirs and their predicted pore pressures are indicated in the attached M -17 Plan Summary. (C) Due to ongoing production operations in this field, sub - normally pressured sands occur in multiple places. Lost circulation and differential sticking are potential problems. Conventional solutions such as LCM and good drilling practice are intended to ameliorate the problems. An exception to 20 AAC 25.035 (c)(1)(B) is requested. The diverter system at Steelhead includes two 16" diameter diverter lines. The surface hole section of M -17 is planned to be drilled with a 17 1 /2" bit. Union Oil Company of California / A Chevron Company Page 1 of 2 i • In accordance with 20 AAC 25.050 (b)(2)(B)... Union Oil Company of California is the only operator of wells within 200' of the planned trajectory of M -17. Pursuant to 20 AAC 25.005 (c)(14)... Qualified drilling waste will be discharged in accordance with NPDES permit AKG -31 -5000 which became effective 7/2/2007 and expires 7/2/2012. At this point, Union Oil Company does not intend to apply for annular disposal approval. The remainder of the requirements of 20 AAC 25.005 are attached for review or are on file with the Commission. Additionally, our records indicate bond number 086S103515406BCM replaced bond number 5534278. It appears that your records might indicate bond number 5534278 is still in effect. If you have any questions, please don't hesitate to contact myself or Jim Rose at 907 - 263 -7637. Sincerely, AO 9 Timothy C. Brandenburg Drilling Manager Attachments: Form 10-401 in Duplicate M -17 Cementing Calculations M -17 Well Plan Summary M -17 Casing Design M -17 Summary Drilling Procedure M -17 MASP Calculations M -17 Summary Mud Program M -17 FIT / LOT Procedure M -17 Planned Well Sketch M -17 Spider Plots M -17 Planned Well Trajectory M -17 BOP Schematic M -17 Choke Manifold Schematic M -17 Diverter Schematic M -17 Drilling Hazards Notice Cc: File Union Oil Company of California / A Chevron Company Page 2 of 2 • Chevron %110 Steelhead Platform Well M -17 Well Design Summary M -17 Well Design Summary Steelhead M -17 is a development well drilled in a SSE direction from slot Al - 9. The well penetrates multiple primary and secondary Grayling Gas Sand targets from the SZ11 at 1475' TVD through the D16C at 6120' TVD. M -17 is designed as an "S" shaped well reaching 58 degrees inclination in the tangent section and reaching a total depth of 7630' MD, 6343' TVD. Basic Well Information Platform: Steelhead Well Name: M -17 Estimated Spud Date: 9/22/07 Field: McArthur River Productive Horizon: Grayling Gas Sands PTD: TBD Total Depth: 7630'MD, 6343' TVD Slot: Slot Al -9, SW Leg Surface Location: 1052' FNL, 455' FWL, Sec 33, T9N, R13W, SM X= 214070, Y= 2499450, NAD27, ASP, Zone 4 Planned BHL: 4688' FNL, 342' FEL, Sec 32, T9N, R13W, SM Original KB Elevation: 160' AMSL KB to BF: 78' Casing and Tubing Program Hole D Weight Grade Conn Length MD/TVD MD/TVD Size (in) (in) (lbs / ft) (ft) (ft) (ft) Driven 28 -32 X -56 Weld 402 BF 480 17'/2 13 3/8 68 L -80 BTC 772 BF 850/850 12 1/4 9 5/8 40 L -80 BTC 1342 BF 1420/1400 8 '/2 7 26 L -80 BTC -M 5643 BF 5721/4690 6 1/8 5 18 L -80 H513 2109 5521/4517 7630/6343 TBG 3'/2 9.2 L -80 IBT -M 5443 BF 5521/4517 8/30/2007 Page 1 of 3 • • Chevron 1%. Steelhead Platform Well M -17 Well Design Summary Well Control Summary Hole Section Equipment Test Pressure (psi) „ 21 '/4 2M Diverter c/w 2 ea 16" 600 psi Diverter Function 17 /2 Valves* 16 3/4" 5M Annular, 16 3 /4" 10M Double Gate, 12'/4" 16 3 /" 10M Cross, 16 3 /" 10M Single Gate, 250/4000 3 '/8" 5M Choke Manifold* 16 3 /" 5M Annular, 16 3/4" 10M Double Gate, 8 '/2" 16 3/4" 10M Cross, 16 3 /" 10M Single Gate, 250/4000 3 '/8" 5M Choke Manifold* 16 3 /4" 5M Annular, 16 3 /4" 10M Double Gate, 6 '/8" 16 3 /" 10M Cross, 16 3/4" 10M Single Gate, 250/4000 3 '/8" 5M Choke Manifold* * Schematics of the well control equipment are attached for reference Anti - Collision Evaluation Summary There are multiple close approach wells. All wells pass major risk criteria. The following wells represent the closest approaches. Close Approach M -17 Path Ellipse Separation Diverging From Well (MD ft) (ft) (ft) M -13 448 1.3 (inside conductor) 520 M -14 900 3.66 900 Formation Integrity Testing Test Point, 20' Pr Depth d Test Type Projected Test Below... (TVD) (EMW ppg) 13 3/8" Csg Shoe 870 FIT 12.8 9 5/8" Shoe 1419 FIT 12.8 7" Shoe 4707 FIT 13.5 8/30/2007 Page 2 of 3 w • • Chevron ft. Steelhead Platform Well M -17 %0 Well Design Summary Mud Program Summary Section Depth Mud Type Density Viscosity PV YP API FL (MD ft) (ppg) (sec) 17 '/2" Surf. 0 -850 Pre -Hyd Gel 9.0 -9.2 60 -85 10 -28 25 -35 <12 12 '/4" Interm. 850 -1420 Pre -Hyd Gel 9.1 -9.2 60 -85 10 -28 25 -35 <10 8'/2" Interm. 1420 -5721 KCL /GEM /Pmr 9.1 -9.2 40 -53 6 -15 13 -20 <_6 6 1/8" Prod. 5721 -7630 KCL /GEM /Pmr 9.1 -9.2 40 -53 6 -15 13 -20 <_5 Cementing Summary See Attachments Formation Markers Target Top TVD /SS Depths Measured Pore Pressure EMW Requirement Depth (RKB) V5 (PSI) (RKB) SZ11 -1315 1497 675 8.4 ppg SZ12 -1455 1662 300 3.6 ppg , SZ17 -1915 615 5.7 ppg i SZ22 -2316 2256 615 3.1 ppg A2 -2530 3331 490 3.5 ppg B3 -3190 4167 285 1.7 ppg B4 -3265 4257 425 -1500 2.4ppg - 8.6 ppg , B5 -3415 4436 425 2.3 ppg Cl -3760 4832 375 1.9 ppg C5 -4010 5120 1810 8.5 ppg Dl -4160 5582 840 3.8 ppg D2 -4455 5651 600 2.5 ppg D3B -4640 5848 650 2.6 ppg D6 -4935 6188 900+ 3.4 ppg+ D14 -5795 7181 2640 8.6 ppg D16C -5970 7372 322 -900+ 2.9 ppg TD -6183 7630 8/30/2007 Page 3 of 3 Chevron Steelhead Platform Well M -17 %.1 Basic Drilling Procedure M -17 Basic Drilling Procedure 1. RU Steelhead rig over slot Al -9. 2. Install A section wellhead and test. 3. Install 21 1 /4" 2M diverter and dual 16" diverter lines and test. 4. MU 17 bit and clean out conductor to 448'. 5. MU jet wash tool and wash out conductor to 448'. 6. RU Gyro and survey conductor. 7. MU 17'/2" directional BHA and drill to 850' taking gyro surveys as necessary. 8. Run and cement 13 3/8" casing to surface in 2 stages utilizing an ECP stage collar. 9. NU and test 16 3/4 10M BOP's 250/4000. Test casing to 1500 psi. 10. MU 12 ' / " directional BHA and drill out. Perform FIT to 12.8 ppg EMW. 11. Directionally drill to 1420' taking gyro surveys as necessary. 12. Install 9 5/8 rams and test. Run and cement 9 5/8 casing to surface in 2 stages. 13. Redress BOP's and test 250/4000. Test 9 5/8" casing to 2500 psi 14. MU 8 1 /2" directional BHA and drill out. Perform FIT to 12.8 ppg EMW. 15. Directionally drill to section TD at 5721: 16. Pull wiper trip and TOOH for logs. 17. Run OH logs. 18. Install 7" rams and test. Run 7" casing and cement to 920' in 1 stage. 19. Redress BOP's and test 250/4000. Test 7" casing to 3500 psi. 20. MU 6 1/8" directional BHA and drill out. Perform FIT to 13.5 ppg EMW. 21. Directionally drill to TD at 7630. 22. Pull wiper trip and TOOH. 23. Install 5" rams and test. Run 5" Liner and cement TD to 5521' in 1 stage. 24. Set liner hanger and liner top packer. 25. Redress BOP's and test 250/4000. 26. PU clean out string and make bit and scraper run to PBTD. Displace to completion fluid. Test casing to 3500 psi. 27. Run 3 1 /2 tubing. Space out and land tubing. Test void. 28. Install BPV and ND BOP. 29. NU tree and test. 30. RDMO Steelhead rig. Through tubing perforating will take place during subsequent operations. 8/30/2007 Page 1 of 1 • • Halliburton BAROID Chevron Mud Program gA�o�1 �' i��la i� Chevron Steelhead M -17 Cook Inlet, Alaska Baroid Mud Program Halliburton Baroid Name (Printed) Signature Date Originator Dave Soquet Reviewed by Dave Higbie Customer Approval Jim Rose Version No: Date: 3.2 Aug 22, 2007 M -17 v3.2 1 8/22/07 • • Halliburton BAROID Chevron Mud Program Surface Hole Recommendations Properties: Density Viscosity Plastic Viscosity Yield Point API FL �H 485'- 850' 9.2 f 60 - 85 10 - 28 25 - 35 <12 8.5 -9.0 System Formulation: Product Concentration Water 0.905 bbl Soda Ash 0.5 ppb Aquagel 15 ppb Caustic 0.1 ppb (9 pH) Barazan D as needed Baroid as required for 9.2 ppg PAC /Dextrid if required for <12 FL Mud Type: Pre- hydrated gel /filtered inlet water spud mud 1. Mud weight: Maintain the 9.0 — 9.2 ppg density or as directed. 2. Rheology: Maintain a YP between 25 - 35 or as needed to achieve adequate hole cleaning.. 3. Filtrate control: Maintain the filtrate <12 cc with PAC. Seepage losses in this interval can be controlled with additions of 3 -5 ppb BAROFIBRE or by dedicated LCM pills. Intermediate Hole Recommendations Properties: Density Viscosity Plastic Viscosity Yield Point API FL �H 850' -1420' 9.2 d 60 - 85 10 - 28 25 - 35 <10 8.5 -9.0 System Formulation: Product Concentration Water 0.905 bbl Soda Ash 0.5 ppb Aquagel 12 -15 ppb Caustic 0.1 ppb (9 pH) Barazan D as needed Baroid as required for 9.2 ppg PAC /Dextrid if required for <10 FL Aldacide G 0.1 ppb Mud Type: Pre - hydrated gel /produced water spud mud 1. Mud weight: Maintain the 9.1 — 9.2 ppg density or as directed. 2. Rheology: Maintain a YP between 25 -35 or as needed to achieve adequate hole cleaning. 3. Filtrate control: Maintain the filtrate <10 using Dextrid and /or Pac L. Additions of Condet may be required to control screen blinding /BHA balling. Losses in this interval can be controlled with additions of 1 -2 ppb BAROFIBRE and 1 -2 ppb of Baracarb 50 or by dedicated LCM pills. 8 -1/2" Hole Recommendations Properties: Density Viscosity Plastic Viscosity Yield Point API FL �H 1420' -5721' 9.1 40 -53 6 - 15 13 - 20 <6 8.5 -9.5 • Additional mud weight may be required for effective coal or shale stabilization. M - 17 v3.2 2 8/22/07 • Halliburton BAROID Chevron Mud Program System Formulation: Product Concentration Water 0.905 bbl KCI 7 ppb (9K chlorides) Caustic 0.2 ppb (9 pH) Barazan D 1.0 ppb (as required 18 YP) Dextrid 1 -2 ppb PAC L 1 ppb Clayseal 4 ppb (initial 1 ppb) Aldacide G 0.1 ppb GEM GP 1.5% by volume Baroid as needed for 9.1 ppg Mud Type: 9.1 ppg KCl/ Clayseal/ GEM System. 1. Mud weight: Maintain the density at 9.1 ppg or as needed; use solids control and whole mud dilution. Increase density as required for hole stability/coal sloughing. Maximize solids control usage. 2. Rheology: Maintain a YP between 13 and 20. Pump high viscosity or Barolift sweeps throughout the interval as needed, particularly prior to POH for casing. Optimized mud rheology and flow rate will be the primary mechanisms for achieving hole cleaning in this deviated wellbore. Maximize pipe rotation (ideally > 100 RPM). 3. Other issues: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to minimize the chances for losses and differential sticking. Production Hole Recommendations Properties: Density Viscosity Plastic Viscosity Yield Point API FL pH 5721' — 7630' 9.2 40 -53 6 - 15 13 - 20 <5 8.5 -9.5 System Formulation: 2% KCI, Clayseal, GEM Product Concentration Water 0.905 bbl KCI 7 ppb (8 -9 K chlorides) Caustic 0.2 ppb (9 pH) Barazan D 1.0 ppb (as required 18 YP) Dextrid 1 -2 ppb Clayseal 4 ppb Aldacide G 0.1 ppb GEM GP 1.5% by volume Baracarb 50 10 ppb Baroid as needed Mud Type: 9.2 ppg KCI /Clayseal/GEM System. 1. Mud weight: Maintain the density at 9.2 ppg or as directed; use solids control and whole mud dilution. Increase density as required for hole stability/coal sloughing. Maximize solids control usage. 2. Rheology: Maintain a YP between 13 and 20. Pump high viscosity sweeps throughout the interval as needed, particularly prior to POH for casing. Optimized mud rheology and flow rate will be the primary mechanisms for achieving hole cleaning in this deviated wellbore. Maximize pipe rotation (ideally > 60 RPM). 3. Other issues: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to minimize the chances for losses and differential sticking. M -17 v3.2 3 8/22/07 Chevron • eelhead Platform ell M -17 W . Draft Well Design 072007 CASING AND TUBING DETAIL RKB to TBG Head = 78'75.00' SIZE WT GRADE CONN MIN ID TOP BTM r - - 28" Conductor (MDrkb) 28" Structural 27" Surface 485' 13 -3/8" 68 L -80 BTC 12.415 Surface 850' lik ECP Stage Collars 9 -5/8" 40 L -80 BTC 8.679 Surface 1420' ' a 13 -3/8" in 17 '/" Hole 7" 26 L -80 BTC -M 6.276 Surface 5721' I 5" liner 18 L -80 H513 4.276 5521' 7630' Tubing 3 -1/2" 9.2 L -80 IBTM 2.992 Surface 5521' TOC @ 920' Target Top TVD /SS Depths Measured Pore Pressure EM Requirement Depth (RKB) (PSI) (RKB) 9 -5/8" in 12''4" Hole VS SZ11 -1315 1497 675 8.4 ppg SZI2 -1455 1662 300 W 3.6 ppg SZI7 -1915 615 5.7 ppg SZ22 2256 615 3.1 ppg A2 -2530 3331 490 3.5 ppg B3 -3190 4167 285 1.7 ppg B4 -3265 4257 425 -1500 2.4ppg — 8.6 ppg I B5 -3415 4436 425 2.3 ppg Cl -3760 4832 375 1.9 ppg C5 -4010 5120 1810 8.5 ppg Profile Nipple DI -4160 5582 840 3.8 ppg D2 -4455 5651 600 2.5 ppg 7" in 8 " Hole D3B -4640 5848 650 2.6 ppg D6 -4935 6188 900+ 3.4 ppg+ D14 -5795 7181 2640 8.6 ppg D16C -5970 7372 322 -900+ 2.9 ppg TD -6183 7630 Logging Requirements: 17 ' /2" Hole: No Logging 12 '/" Hole: LWD only GR/Res /Annular Pressure, Mud Logging. 5" Liner in 6 1/8" Hole 8 '/2" Hole: LWD GR/Res /Dens/Neut/Annular Pressure. ELine: MDT, 9 ea it/Matk pressure only data. Dipmeter, NMR, Mud Logging. 6 1/8" Hole: LWD GR/Res /Dens/Neut/Annular Pressure. MAX HOLE ANGLE = 58 @ Tangent 2,619' -3050' MD Well Detail DRAWN BY: JAR 061907 • • Chevron Chevron �.r Location: Cook Inlet Alaska (Offshore) Slot: slot #A1 -9 Bi �R IC 41110° F ield: M cArthur Ri ver Field Well: M-17 HUGHES Facility: STEELHEAD Platform Wellbore: M-17 INTEQ Plot reference wellpath is M -17 Version #5 True vertical depths are referenced to Actual Datum (RKB) Grid System: NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Actual Datum (RKB) North Reference: True north Actual Datum (RKB) to mean sea level: 160.25 feet Scale: True distance mean sea level to Mud line (Facility - STEELHEAD Platform): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: MichWlG on 5/9/2007 Well Profile Data Scale 1 Inch - 699.9996 Easting (ft) Design Comment MD (11) Inc 1 °) Az ( °) TVD (1t) Local N (ft) Local E (ft) DLS (° /1001[) VS (ft) - 1050 - 700 - 350 0 350 Tie On 0.00 0.000 178.000 0.00 0.00 0.00 0.00 0.00 1 1 1 1 KOP 800.00 _ 0.000 178.000 800.00 0.00 0.00 0.00 0.00 Begin Build-Tom _ 1375.00 23.000 178.000 1359.68 - 113.80 3.97 4.00 11030 EOC 2619.75 58.000 200.000 2295.78 - 880.13 - 174.42 3.00 897.06 Begin Drop -Turn 3050.00 _58.000 200.000 2523.76 - 1222.99 - 299.21 0.00 1258.71 SIOt #A1 - EOC 4009.21 30.000 190.000 3207.70 - 1854.69 - 483.86 3.00 1915.30 0 TD 7624.30 30.000 190.000 6338.48 - 3634.77 - 797.74 0.00 3721.29 M17 Tgt A (19- Sep -06) - -350 e: -750- ■ -700 illi 0- ■ -10b0 750 - KOP -1400 4.00 °11 OOft Z 0 Begin Build - Tum - 1750 s M17 Tgt A (19 Sep - 06) 7 0 fQ t B 83(19- Sep -06) 3.00 ° /100ft -2100 2250 - EOC Begin Drop -Turn 1 M17 Tgt C Cl (19- Sep -06) IS 3.00 °1100ft N 3000 M17 Tgt DD3B(19- SepE 8 M17 Tgt B B3(19- Sep -06) EOC r B5ST f0 3750 - - -2800 N M17 Tgt C C1 (19- Sep -06) T illorgo M17 Tgt E D6 (19 -Sep 4 2 C5ST R §T 4500 - -3150 M17 Tgt D D38 (19- Sep -06 •ST M77 Tgt FF i g h M17 Tgt E D6 (19- Sep -06) , : .ST - 5250 - 4500 M17 Tgt G TD D14ST - -3650 6000 - M17 Tgt FF • • ST MI7 Tgt GTD N 6750 - W N. ��/yY�. 1 1 1 1 1 1 I 7 / 5 0 750 1500 2250 3000 3750 4500 9GGM (1995.0 to 2003.0) 0ip: 73.61 9991 55513.6 nT Magnetic North Is 19.33 degrees EaM 01 1 North (at 09(19(06) Vertical Section (ft) Sca1e 1 loch - 15006 To correct azimuth from McBnei0 to True 89919.33 969,686 Azimuth 192.38° with reference 0.00 N, 0.00 E from wellhead • i _ Chevron Planned Well path Report I 410. M -17 Version #5 r HUGHES Page 1 of 5 INTEQ REFERENCE WELLPATH IDENTIFICATION O perator Chevron Slot slot #A1-9 Area Cook Inlet Alaska (Offshore) Well M-17 Field - McArthur River Field Wellbore M -17 Facility jSTEELHEAD Platform REPORT SETUP INFORMATION Projection System NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Software System 1WellArchitectTM 1.2 North Reference [True User MichWilG Sc 10.999993 Report Generated 05/09/07 at 11:21:25 Wellbore last revised 04/27/07 Database /Source file .WA _Anchorage/M -17 xml WELLPATH LOCATION Local coordinates Grid coordinates Geographic coordinates North [feet] j East [feet] Easting [US feet] ' Northing [US feet] Latitude [ °] Longitude [°] Slot Location 1052.80 455 34 _ ^ _ `— i � 214070 16 2499450 47 60 49 54.436N � 15 36 08.833W _ —_ !Facility Reference Pt ; 213640.71 2500514. 08 60 50 04.803N E 151 36 18.018W [ie1d Reference Pt I 213640.71 1 2500514 08 60 50 04.803N 151 36 18.018W WELLPATH DATUM 1 Actual Datum (RKB) to Facility Vertical Calculation method 'Minimum curvature Datum 1160.25 feet H� onzontal Reference Pt [Slot Actual Datum (RKB) to mean sea level '160 25 feet Vertical Reference Pt FActual Datum (RKB) Facility Vertical Datum to Mud Line (Facility) 0.00 feet MD Reference Pt 'Actual Datum (RKB) 'Section Origin N 0.00, E 0.00 ft Field Vertical Reference 1mean sea level Section Azimuth 192.38° . • 410 NW Chevron Planned 7� ��� ���� -m �°=~~~=~~�� ry =.�u m��m'��~°�� � Report ��������N0�� w�"���m��^� P��c2of5 ��������� NW. �^n�m��� REFERENCE WELLPATH IDENTIFICATION Operator Chevron 'Slot slot l'� - - --- _ Cook Inlet, Alaska Well 00 7 - __ - McArthur River Fie0i \�c}bon� M-17 l FuuiK� \8����DD��� ���- ---- I DATA �� �interpolated/extrapolated __�_�_ station MD Inclination Azimuth TVD ' Vert Sect North ` East Grid East Grid North DLS Build Rate Turn Rate [feet] _ r| M [feet] [feet] [feet] survey feet] [us survey feet] [°onoft] [MOON r/om� 0.00 0 �0O _ O.0O _ 0.0 _ 0.00 214070.16 . 2499450.47 0.00 0.00� 0.00 1050t O�0O 0.00 0�O 0�o���� 21407016 2499450.47 0.00 --- /on / 200.00t 0.000 0.000 200.00 1 0.00 O�O < �0O 21407016 2 O1m - --- 1OO�Ot O�OO i 0�O O�0 | ^-- �� - -- 0.00 400.001' o.000 0{00 400{0 OlN 0.00 0.00 214070.16 500.001' V�OO' _ 0.000 500.00 0 0.00 OlN 214070.16 2499450.47 0.00 V�o 0.00 000 0.000 0.000 600.00 O 0.00 0.00 214070.16 | 24VO4j --- / 0 O1N 0.00 0.000 0.000 700.00 O 0.00 0.00 214070.16 O � 0 O XO800.00 0 8O800.00 0.00 0.00 0{N 2 J) ---- 900.001' 4.00O' 178.000 80992 3.38 '3A9 0.12 21407019 r �x 8.000 178 13.50 -13.93 0.49 214070.30 - 12 30.32 ---- 128 | 21 9 l0\l7 h 16.0001 6 178,000| 1194.82 1- 53.75 '55.45 l 214070.74 24903 4.8 00.00t 20.000 / 178.000 1289.91 8l68 '86.33 l 214071.0 9]64.09 4.00 ' ------ I375{0 28.000 178.000 1359.68 110.30 -113.80 3.97 214071.35 4.00 } 1400.001', 23642' 178.980 1382.64 119.91 '\2l69 423 2l4n7l�37 2499326.71 3.00| l 1500.001' 26.264 DQ�40! 1473.30 161.22 -165.86 3.65 2 -- ---- 2499284.5? 3.00 3. l6O0 28�9�5 18��3O5 l56l9l 2O7�4 '2l2� 'O7 0�7 2� ��5 24A0238�5 3. �OO 2 n "' r - '-- ~�-��---- 1700.001' 3i697 187.718 1648.22 257.26 -262.22 '5.30 214058.46 2499188.46 3.00 2.74 41 r | 189782 1732.00 31173 '31616 21404880 24*9134.74 310 278 . i 37289 191.571 1813.02 i 370.31 -37374 '24.53 214036.51 24990?744 lOO 2�8) ^-- 40.123 193]43 1891.05 1 43283 ~434.81 -37.93 21 240 310 ` 2.83/ l 42.977 \94 �88 499]3 ~499.l0 �3.02 2)4OO4� l6| 2498952.74 \ 31N 2� 05 1.40 O _ - 2200.001' 45.845 195.795 2037.31 569.01 -566.72 -7215 2)398420 249888568 3�0 �87 --- 2300.001' 48.727 196.933 2105.13 642.30 -637.21 -9286 213961.77 24P88l5J] -' 2.88 1- 2400.0 5i6/8|97975 2169.0 71878 '71045 '115 21393694 2498743.06 3.00 2.891 1.04 F' 2500.00fr 54.518 198.936 798.26 '78626 -141 213909.78 24nw 7.89 3.00 29 O 6 57.425 l91&30 2285.21 880.50 'X6443 '/6X.7�T 213880.37 2498590.42 3.00 2.91 2619.75 58.000 200.000 2295.76 89706 -880.13 -174.42 213874.30 2498574.87 3.00 2. 0. 86 58.000 200.000 2338.29 964.51 -944.08 '19770 213849.47 2408511.51 010 0.00 0o6 2800801 50.000 200.000 2391.28 1048.57 '1023.77 -226.70 213818.53 24V8432.55 ! 0.00 0.00 0.00 �Ut 200.000[ 2 lG262| _DO3. -255.71 213787.58 r4v835l50 0.00 080 O.m .001' 58.000' 8.O00 200.000 2497.26 131668 '1183]5 -284J1 213756.64 2498274.63 0o0 --- 0.00 0.00 305010 58.000 200.000 2523.76 125871 '122299 -29921 213741.17 2498235.15 0.00 0.00 0.00 3100.001' 56.525 199.676„4550.80 1300,41 -1262.55 -313.49 213725.94 2498195.95 3.00 -2.95 65 3200.001' 53.578 198.992 2608.08 1381.76 '1339.89 '34062 2B6969l 2490119.31 lOO _-2.95| -0.68 -- .00+ 50.635 198255 266449 }460]9 -1414.66 `3 213669. 3�00 4 7 � 3�� ��� l�*� l��l0 -l�� � ' 2l � �� ~�- ~ ' _ � _- �. .- 3�O03500.00t 4476j 196.572 2804&4 1607.47 -1555.70 -410.18 ` -410.18 213622.11 2407905.26 3.00 -2.93 41.840 195j96 3876.81 1675.90 '1621.59 '42919 213601.50 2497839.86 310 -2.92 '0.98 . 0 0 _ Chevron Planned Well ath Re ort �` p p BAKER M -17 Version #5 HUGHES Page 3 of 5 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator , :Chevron Slot slot #A1 -9 Area 'Cook Inlet, Alaska (Offshore) Well M -17 Field 1McArthur River Field Wellbore M -17 Facility 1STEELHEAD Platform WELLPATH DATA (82 stations) t = interpolated /extrapolated station MD { Inclination Azimuth - TVD Vert Sect North East Grid East Grid North DLS Build Rate Turn Rate [feet] I 1 [ ! [feet] [feet] [feet] 1 [feet] [us survey feet] [us survey feet] ([ ° /100ft] [ ° /1 [ °/100ft 3700.001' 38.925 194.501 2952.97 1740.61 - 1684.14 - 446.03 213583.14 2497777.73 3.00 j -2.92 -1.09 � 3800.001' 36.022 193.260;3032.33 1801.41 - 1743.19 - 460.65 213567.09 2497719.06 3.00 -2.90 1 3900.00t 33.133 191.833 3114.66. 1858.16 - 1798.57 473.00 213553.39 2497664.00 3.00 -2.89 -1.43 4000.001' 30.263 190.168 3199.73 ' 1910.68 - 1850.14 483.05 213542.071 2497612.70 3.00 -2.87 -1.67 4009.21 „' 30.000 190.000 3207.70 1915.30 - 1854.69 483.86 213541.15 2497608.16 3.00 2.86 1.82 L 4100.00t 30.000' 190.000 3286.33 1960.65 - 1899.39 491.74 213532.18 i 2497563.67 0.00 0.00' 0.00 1 4200.00t 30.000 190.000 3372.93 2010.61 - 1948.63 - 500.43 213522.30 2497514.65 0.00 0.00 0.00 4300.00'1 30.000 190.000 3459.53 2060.57 - 1997.87 - 509.11 213512.42 2497465.64 0.00 0.00 0.00 ___.. - 2047.11 - 517.79 213502.54 2497416.63 0.00 0.00 0.00 4500.00 4400.001' 30.000. 190.000 3546.13 2110.52 - _ t 30.000 190.000 3632.74 2160.48 - 2096.35 - 526.47 213492.65 249736 7.61 0.00 0.00 'Of) 4600.001 30.000 190.000 3719.34 2210.44 i - 2145.60 - 535.16 213482.77 2497318.601 0.00 0.001 0.00 4700.00 30.000 190.000 3805.94 2260.39. - 2194.84 - 543.84 213472.89 2497269.59 0.00 0.00 0.00` 4800.001', 30.000 190.000 3892.54 2310.35 - 2244.08 - 552.52 213463.01 2497220.57 0.00 0.001 0.00 4900.00t 30.000 190.000 3979.15 2360.31 - 2293.32 - 561.20 213453.12 2497171.56 0.00 0.00' 0.00 5000.00t 30.000 190.000 4065.75 2410.26 - 2342.56 - 569.89 213443.24 2497122.55 0.00 0.00 ` 0.00' 1 5100.001' 30.000 190.000' 4152.35 2460.22 - 2391.80 - 578.57 213433.36 i 2497073.53 0.00 0.00 0.00` 5200.001' 30.000 190.000 4238.95 2510.18 - 2441.04 - 587.25 213423.48 2497024.52 0.00 0.00; 0.00 _______ 5300.001' 30.000 190.000, 4325.56 2560.14 - 2490.28 - 595.93. 213413.60 2496975.51 0.00 0.00 0.00 1 30.000 190.000 44 2610.09 - 2539.52 - 604.61 213403.71 2496926.49 0.00 0.00 0.00 5500.00f 30.000 190.000 4498.76 2660.05 - 2588.76 - 613.30 213393.83 2496877.48 0.00 0.00 0.00 �__ 5600.001', 30.000 190.000+ 4585.361 2710.01 ' - 2638.00 - 621.98 213383.95 2496828.47: 0.00 0.00 0.00 5700.001' 30.000 190.000 4671.971 2759.96 - 2687.24 - 630.66 213374.071 0.00 0.00, 0.00 58 0.00' 30.000 190.000 4758.57 2809.92 - 2736.481 - 639.34 213364.181 2496730.44 0.00 0.0011 0.00 5900.00t 30.000 190.000 4845.17 2859.88 - 2785.72 - 648.03 213354.30 2496681.43 0.00 0.00 0.00 6000.00t 30.000 190.000 4931.77 2909.83 - 2834.96 - 656.71 213344.42 2496632.41 - 0.00 0.00 0.00 6100.001' 30.000' 190.000 5018.38 2959.79 - 2884.20 ; - 665.39 213334.54 2496583.40 0.00 0.00, 0.00 6200A01' ® 3 0.0 190.000 5104.98 3009.75 - 2933.44 r 674.07 213324.66 2496534.39 0.001 0.001 0.00. 6300.00' 30.000 190.000 5191.58 3059.70 - 2982.68 - 682.76 213314.77 2496485.37 0.00 0.00 0.00 6400.00t 30.000 190.000 5278.18 3109.66 - 3031.92 - 691.44 213304.89 2496436.36 0.00 0.00 0.00 6500.00t 30.000 190.000 5364.79 3159.62 - 3081.16 - 700.12 21.3295.01 2496387.35 0.00 0.00- 0.00 6600.001 30.000 190.000 5451.39 3209.58 - 3130.40 ; - 708.80 213285.13 2496338.33 ! 0.00 ; 0.00 0.00' 6700.00t 30.0001 190.0001 5537.99 3259.53 - 3179.641 - 717.49 213275.24 2496289.32 0.001 0.00 0.00 6800.001' 30.000 190.000 5624.59 3309.49 - 3228.88 - 726.17 213265.36 2496240.31 0.00 0.00 0.00 6900.001' 30.000 190.000 5711.20 3359.45 - 3278.12 - 734.85 213255.48 2496191.29 0.00 0.00 0.00" 7000.00t 30.000 190.000 5797.80 3409.40 - 3327.36 - 743.53 213245.60 2496142.28 0.00 0.00 0.00 7100.001' 30.000 190.000 5884.40 3459.36 - 3376.60 - 752.22 213235.72 2496093.27 0.00 0.00 0.00: [ 7200 30.000 190.000 5971.00 3509.32 I -3425.851 - 760.90 213225.83 2496044.26 0.00 0.00 0.00 7300.00t 30.000 190.000 6057.61 3559.27 - 3475.09 - 769.58 213215.95 2495995.24 0.00 0.001 0.00 7400.001'' 30.000 190.000 6144.21 3609.23 - 3524.33 - 778.26 213206.07 2495946.23 0.00 0.00 0.001 7500.001' 30.000 190.000 6230.81 3659.19 - 3573.57 - 786.95 213196.19 2495897.22 0.00 0.00 0.00 . , 0 • Chevron Mill %MO Planned Wellpath Report M-17 Version #5 BAKER HUGHES III. Page 4 of 5 INTEQ REFERENCE WELLPATH IDENTIFICATION !Operator Fc hevron lot slot #A1-9 lArea Kook Inlet, Alaska (Offshore) Well M-17 Field McArthur River Field Wellbore M-17 Facility [SiEELHEAD Platform ELLPATH DATA (82 stations) t = interpolated/extrapolated station MD 1 Inclination : Azimuth 1 TVD : Vert Sect 1 North ' East - Grid East ,r Grid North T 1311 Turn Rate [feet] 1 r] . 1_ 1 1 , [feet] [feet] [feet] [feet] i [us survey feet] 1 [us survey feet] r/100ft] r/100ft] r/100ft] 1 30.0001 190.000, 6317.411 3709.14 [ -3622.81 [. -795.63 ' 213186.30 2495848.201 0.001 _ 0.00 0.00 1 30.000 190.000 372129-363477 -797.74 213183.901 2495836.291 0.001 0.00 0.00 -.- HOLE & CASING SECTIONS Ref Wellbore: M-17 Ref Wellpath: M-17 Version #5 I -- - String/Diameter Start MD 1 End MD Interval Start TVD I 1-- End TVD ' Start N/S Start E/W Find N/S ri [feet] [feet] [feet] L [feet] I [feet] [feet] 1 [feet] 1 [feet] [feet] F Surface 0.00; 999.00 999.00 i 0.00r 998.36 0.007 0.001 - 13.791 0.48 ,--- - I1i:3 Casing 0.001 1099.00 1099.00 0.001 1096.831 0.001 0.00r -31.07r 1.09 { 9.625in Casing Intermediate 0.00 1204.35 1204.35 0.00' 1199.00, 0.00 0.00 i - - 5 6 .66 [ 1.98 _ ._... .., 17in Casing Intermediate , a 0.00 1309.69 1309.691 0.001 1299.00! 0.00 0.00! -89.671 3.13 _, [Casing Production I 0.001 1417.84F 1417.89 , 0.001 1399.001 0.001 0.001 -130.937 4.32 TARGETS Name ,FM ' TVD North ' East ' Grid East Grid North F' Latitude i l Longitude - 1 Sha p e l[feet] i [feet] i [feet] i [feet] , [us survey feet] ! [us survey feet] , [ 1 19 I ,--- ' 1483.25 - 131.371 87.38 214154.30r 2499317.00 r60 49 53.142NF151 36 07.070W [M17 Tgt A (19 ' 13330.25, 213496.10r 2497549.00! 60 49 35.578NI 151 36 19.471* 1M17 Tgt B B3(19 1 1 3928.251-2251.151-573.06 213442.309724.00[60 49 32.268Nr5 36 20.390Wicircle 1M17 Tgt C Cl (19-Sep-06) ( 24 1 r 1 D3B (19 4794.251-2706.391-658.87, 213345.401 2496761.00r 60 49 27.785N1151 36 22.121W [circle M17 Tgt D r r 1--- ,--- - - '- 5080.251-2837.221-650.171 213350.90; 2496630.00 60 49 26.496N1 151 36 21.945W [- circle M17 Tgt E D6 (19-Sep-06) F- i 6162.00i -3534.441-780.05 213204.041 2495936.161 60 49 19.630N1 151 36 24.563Wicircle M17 Tgt FF M17 Tgt G TD r - , i 633816 1-3634.77 ! -797.74 213183.901 2495836.29 60 49 18.642N115 24.920W circle ' 1 1 , SURVEY PROGRAM Ref Wellbore: M-17 Ref Wellpath: M-17 Version #5 Start MD i End MD Positional Uncertainty Model ' Log Name/Comment i Wellbore [feet] 1 [feet] 1 , ,„ r 0.001 1080.00Gyrodata standard - GWD or Single-shot 1 N1-17 1080.00r 7624.30NaviTrak (Magcorrl) 1&E-17 • 0 _ Chevron Planned Well ath Re ort RBI p P BAKER M -17 Version #5 HUGHES Page 5 of 5 INTEQ REFERENCE WELLPATH IDENTIFICATION Operator Chevron 7 S1ot slot #A1 -9 i A a Cook Inlet, Alaska (Offshore) Well 'M -17 IFie1d 1MeArthur River Field Wellbore 1 M -17 Facility rTEELHEAD Platform WELLPATH COMMENTS MD 3 Inclination r Azimuth TVD , Comment [feet] , [degrees] [ degrees] __. [degrees] [feet] 1626.77 29.684 185.9913 1585.25 SZ11CT , 1720.07 32.252 188.1581 1665.25 SZ12CT 3261.31, 51.773 198.5471 2645.25 IACT 3340.11 49.455' 197.942 2695.25 A2ST 3977.37; 30.911; 190.5691 3180.25 ;BCT 4433.62, 30.0001 190.000 3575.25 IB5ST 4791.58; 30.000 190.000 3885.25'CCT 4837.77 30.000 190.0001 3925.25 IC1ST _. 5120.67 ; 30.000 190.000 4170.25105ST 3 5247.69 30.000' 190.000 4280.25 f DCT 5288.101 _ 30.000 190.000r - 4315.25 D1ST 5813.49 ; ` � 30.0001 190.000 00 4770.25 D3BST - 6177.22; 30.000 190.000 5085.25 [MST 7141.391 F11- 190000 5920.25 D14ST 1-- 7383.88; 30.000 190.000 6130.251D16CST 7580.18 30.000 ! 190.000 6300.251ECT _ DESIGN COMMENTS __ __ __� __ _ MD Inclination Azimuth TVD I Comment [feet] 1 [degrees] 1 [degrees] [feet] 0.00 0.000' 178.000 i 0.00 'Tie On 800.001 0.000; 178.0001 800.001KOP 1375.00 ' 23.000 178.000 1359.68 Begin Build Turn F ----J, 2619.75; 58.000 I 200.000 r 2295 76 EOC 3050 001 58.000 200 0001 - 2523.76 Begin Drop -Turn 4009 21 30.000 190.000 3207.70,E0C 7624.30 30.000; 190.000 ~ 6338.46ITD • • M -17 21.25 inch Diverter dwg.xls . _ 82.18' 6.50' w I a L 0.5 7 29.50' has been built its on SH needs ad & flow line • 21.71' 22" • • • • Flow Nipple S. HydriI 2000 MSP 4.38' 21 1 /4" R- 73 4.38' J �30" x 20 114" DSA - Diverter pipe OD .37" 20 1/4" s° soo Diverter Spool 1s" six) Rail Valve_ _ _ _ Ball Valve_ • I Centerofporton r S ♦ 3.35' Rig sub 28" ID 1.60' Q7Di-- - • - - - -: -- -- -- � 3.35' + Rig Sub Grating Floor up to center of Spool 48.69' 30" Riser Section 28" ID 23.47' With 30" MSS Series 300 Flange Needed For Nipple UP On Top X 20.86' 4- each R -95 Ring Gaskets 2- each Dril -Quip DX Seal Rings 30" 30" Dril- Quip Spare Drill Quip Long & short Bolts Quik Clamp 84 1 3/4" x 13" studs On Bottom 168 2 3/4" x 1 3/4 Nuts ( each etre of above for Flow nipple) Torque wrench, for 200 ft lbs on on Dril -Quip Quick clamp connector Diverter line Nipple up 160 each 1 1/2" x 10 1/4" Studs 320 each 2 3/8" x 1 1/2" Nuts 8 each 16" 600 flange gaskets Hydraulic line Hook up Choke line to Noth Diverter Valve Kill line to South Diverter Valve Annular ( Close) to annular • ♦ Upper well bay room floor 30" Dril -Quip Quick Clamp Connector Top & Bottom 16.80' 1 Note : The 16.80 Riser section has min ID of 27.8125" due to some irregularity • due to welding on of the 30" clamp Top of grating in well room 30" Riser section with du um-chip l..IUICK.0 connector on top & 30" Ill 6.11' MMS Flange on Btm 4.23 Short 30" Riser Section \� FINISHED LENGTH AFTER CUT 22.88' 5.83 -1.60= 4.23' VETCO HEAD 2 -30 Degree • 6" outlets Flang • i 1 2.05' 1.60' ♦ 1 • ♦ ♦ ♦ M -17 21.25 inch Diverter dwg.xls • • Steelhead M -17 16 3/4" BOP Stack up Top of Rotary Table KB ' • • 4 6.75' 82.18' 36.25' Bottom drip pan GAP = 6.80' 163/4 "5M • 57.66' Hydril Annular ♦ 5.40' 5.40' • � T f 163/4 "10MH Y driI DBL Gate Pipe Rams 6.03' • 6.03' Blind Rams iimw � I • • • Choke line _ _ ��mm' Kill Line Hyd Kill line 16 3l4" 10M t'( " HCR Valve — Mud Cross ",... 2.45 OR CHECK 2.45' VALVE ALL Wing valves 3" 5M • / 1 16 3/4" 10M Single Gate 3.75" 3.75' 1 • ,Rig Sub Grating 1a +u 5M Riser 19.98' Hub Connection • F6 3/4" 5M BX 162 20.05' 16 3/4" 5M 20.05' Riser Hub Connection on top • Upper well Bay Floor Flanged Bottom 22.88' • • • 16 3/4" x 13 5/8" DSA • .60' Tubing Completion Spool I 13 518" 5m a% VETCO 2.21' 7" Casing Spool VETCO 13 " 5m ( 4 2.21' Grating 13 5/8" 5M 9 5/8" Casing Spool (�� 6.11' VETCO �� • 30" Vetco Head 1 10.97' • • . .... Ring sliped over 26" & But weld to 28" • v7 I . L Li ILM L5 4 L. f1 4 i V i i III .:f. . CHOKE MANIFOLD • TO GAS BUSTER • TO DERRICK VENT TO SHALE SHAKERS rc41 (titi ,( . I\ mi . s ii, A : .,...,,„ _,... - I _ '° tiliMi 44101 "MCI . t•• . 7.11111111113t .. • . =HIM li . — 1 Asi-- 11. 7T joraull dip lie , 4 II :;. i ' r' - 1 SWACO am li 4 ilaprA ifer/e/....air 4, * i r • Ds' - • . _.._ �� CHOKE LINE I A-- SECTION AA * ALL VALVES IN FLOW PATH ARE 3 -1/16' 5000 PSI CAMERON GATE TYPE • AD 018772 UNOCAL 21 OCAL McArthur River Field Steelhead Platform M -17 Well Proposal 1,500 750 0 1,500 .■•• Feet i t 29 28 27 ADL017594 •GRAYLING UNOCAL FOREST ADL018730 UNOC - -AL 4 MARATHON • 32 33 34 M -17 Proposed • T9N -R13W T8N - R13W ADL018729 ADL017579 6 UNOCAL 5 4 UNOCAL MARATHON FOREST • Steelhead M -17 Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE 17-1/2" and 12-1/4" Hole Sections • Shallow gas sands will be encountered that have the potential to flow and cause a loss of well j control. All operations shall proceed with the necessary precautions to prevent a kick. Special attention is required in the following areas: 1. Monitor trip tank on each trip into and out of the hole. 2. Carefully monitor PVT for gain / loss. 3. Have LCM material onboard and ready for use in the event significant losses occur. 4. Minimize surge and swab pressures while tripping. 5. Review cement spacers and washes to ensure the well is not under balanced at any point during cementing operations. 6. Perform diverter drills until the crews are familiar with the procedure. • M -13, M -14 and M -15 are all critical close approach wells. Record annulus pressures on these wells prior to spud and monitor during the drilling of the surface and 1st intermediate hole sections. 8-1/2" (2 Intermediate Hole Section: • Significantly under pressured reservoir sands will be encountered A heightened awareness of kick detection, pre -job planning and trip tank calibration will be essential while drilling /tripping the intermediate interval. • Loss circulation is considered to be a major risk due to the depleted reservoir sands which will be encountered. Loss circulation materials will be readily available for adding to the mud system should significant losses be encountered. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures • Differential sticking is a considerable risk while drilling these depleted sands. Keep the drill string moving whenever possible. • Numerous coals will be drilled through. Unocal coal drilling strategy; limiting the amount of coal drilled ( <10') prior to back reaming should be followed. 6-1/8" Production Hole Section: • Significantly under pressured reservoir sands will be encountered A heightened awareness of kick detection, pre -job planning and trip tank calibration will be essential while drilling /tripping the production interval. • Loss circulation is considered to be a major risk. Loss circulation materials will be readily available for adding to the mud system should significant losses be encountered. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures • Differential sticking is a considered a major risk. Keep the drill string moving whenever possible. HYDROGEN SULFIDE - H2S • Steelhead is designated as an H2S drill site. Standard Operating Procedures for H2S precautions should be followed at all times. Version 1.0 Rigsite Hazards and Contingencies Chevron Steelhead Platform Well M-17 Drilling Program 2007 M -17 Cement Calculations Surface Casing 13 3/8 ", 68 ppf, Surface Casing in 17 Hole, Stage 1 Cement from section TD at 850' to the ECP stage tool at 480'. OH Volume w/ 100% excess = (850- 480) *0.1237 *2 = 91.6 bbls Shoe Track Volume = 80 *0.149 = 11.97 bbls Stage 1 Total Volume = 91.6+11.97 = 103.6 bbls of 15.8 ppg GasBlok G Slurry 13 3/8 ", 68 ppf, Surface Casing in 34 OD x Various ID Structural Pile Conductor, Stage 2 Cement from 470' to surface (ECP is 10' long). • Annular Volume] = 470 *0.7005 = 329 bbls Stage 2 Total Volume = 329 bbls of 15.8 ppg GasBlok G Slurry. Notes: 1 Used 30" ID as average for volumetric calculations. Chevron 11%. Steelhead Platform Well M -17 Drilling Program 2007 Intermediate Casing 1 9 5/8 ", 40 ppf, Intermediate Casing Inside 12 1 /4" Hole, Stage 1 • Cement from section TD at 1420' to ECP stage tool at 850' OH Volume w/75% excess = (1420- 850) *0.0558 *1.75 = 55.66 bbls Shoe Track Volume = 80 *0.0732 = 5.86 bbls Stage 1 Total Volume = 55.66 + 5.86 = 61.5 bbls of 15.8 ppg GasBlok G Slurry. 9 5/8 ", 40 ppf, Intermediate Casing inside 13 3/8, 68 ppf, Casing, Stage 2 Cement from 840' to surface (ECP is 10' long). Annular Volume = 840 *0.0597 = 50.1 bbls • Stage 2 Total Volume = 50.1 bbls. • Chevron Steelhead Platform Well 7 Drilling Program 2007 Intermediate Casino 2 7 ", 26 ppf, Intermediate Casing Inside 8'/2" Hole Cement from section TD at 5721' to 920' (500' inside the 9 5/8" casing) • OH Volume w /50% excess = (5721 - 1420) *0.0226 *1.5 = 145.8 bbls Shoe Track Volume = 80 *0.0383 = 3.1 bbls Cased Hole Annular Volume = 500 *0.0256 = 12.8 bbls Total Cement Volume = 145.8 + 3.1 + 12.8 = 161.7 bbls of 12.0 ppg LiteCRETE Uni- Slurry Production Liner 5 ", 18 ppf, FJ liner inside 6 1/8" Hole Cement from section TD at 7630 to 5521 (200' liner lap) • OH Volume w /50% excess = (7630 -5721) *0.0122 *1.5 = 34.9 bbls Shoe Track Volume = 80 *0.0178 = 1.4 bbls Cased Hole Annular Volume = 200 *0.0140 = 2.8 bbls Total Cement Volume = 34.9 + 1.4 + 2.8 = 39.1 bbls of 15.8 ppg G LXT Slurry Chevron W I Steelhead Platform %. Well M-17 Drilling Program 2007 M -17 Casing Design Tensile Tensile Design Design Design Internal Collapse Strength Strength Safety Safety Safety • Size Wt Yield Resistance Body Conn MD TVD Factor Factor Factor (in) (ppf) Grade Conn (psi) (psi) (M Ibs) (M Ibs) (ft RT) (ft RT) T B C 28 Structural' 13 3/8 68 L -80 BTC 5020 2270 1556 1540 850 848 31.01 13.75 5.84 9 5/8 40 L -80 BTC 5750 3090 916 947 1420 1400 18.81 7.84 4.77 7 26 L -80 BTC -M 7240 5410 604 _ 641 5721 4690 4.06 4.38 2.71 5 18 L -80 Hyd513 9910 10490 422 319 7630 6343 3.31 5.99 3.61 Notes: Existing 28 " -32" OD structural pile conductor set in 1986. 2 Tension safety factor is calculated with buoyancy effects. 3 Burst safety factor is based on MASP. 4 Collapse safety factor assumes evacuated casing. 0 1 Chevron 11%. Steelhead Platform Well M -17 %101 Drilling Program 2007 M -17 Maximum Anticipated Surface Pressure Calculations 17'/2" Surface Hole, 13 3/8 Casing The 17'/2" surface hole will be drilled to approximately 850' MD /TVD under an existing structural pile conductor • and will use a diverter system for well control. The diverter system is not designed to shut the well in and contain pressure. MASP is 0 psig for this hole section. 12 'A" Intermediate Hole Section, 9 5/8" Casing The 12'/4" intermediate No. 1 hole section will be drilled from 850' MD /TVD to 1400' TVD. MASP will be the lesser of Bottom Hole Pressure ASP from the deepest exposure or Fracture Gradient ASP at the deepest casing shoe. FG ASP Predicted Fracture Gradient = 12 ppg 850 x 12.0 x 0.052 = 530 psig. Correcting for gas gradient -* 530 - (850 x 0.10) = 445 psig Therefore, FG ASP = 445 psig BHP ASP Depth of next hole section = 1400' TVD. Mud wt at TD = 9.8 ppg. Maximum predicted pore pressure at TD = 9.3 ppg. / Chevron 111110 Steelhead Platform Well M -17 MI NO Drilling Program 2007 Pressure of gas column —> 0.7 x 1400 x 0.10 = 98 psig Pressure of mud column --* 0.3 x 1400 x 9.8 x 0.052 = 214 psig Pore pressure = 1400 x 9.3 x 0.052 = 677 psig Therefore, BHP ASP = 677 - 214 - 98 = 365 psig MASP = 365 psig • 8 Y2" Hole Section, 7" Casing The 8'12" intermediate No. 2 hole section will be drilled from 1400' TVD to 4690' TVD. MASP will be the lesser of Bottom Hole Pressure ASP from the deepest exposure or Fracture Gradient ASP at the deepest casing shoe. FG ASP' Predicted Fracture Gradient = 12 ppg 1400 x 12.0 x 0.052 = 874 psig. Correcting for gas gradient —* 874 - (1400 x 0.10) = 734 psig Therefore, FG ASP = 734 psig BHP ASP Depth of next hole section = 4690' TVD. Mud wt at TD = 9.8 ppg. Maximum predicted pore pressure at TD = 9.3 ppg. Pressure of gas column —* 0.7 x 4690 x 0.10 = 328 psig Chevron IWO Steelhead Platform Well M -17 Drilling Program 2007 Pressure of mud column -* 0.3 x 4690 x 9.8 x 0.052 = 717 psig Pore pressure = 4690 x 9.3 x 0.052 = 2268 psig Therefore, BHP ASP = 2268 - 717 - 328 = 1223 psig MASP = 734 psig 6 1/8" Hole Section, 5" FJ liner The 6 1/8" production hole section will be drilled from 4368' TVD to 6343' TVD. MASP will be the lesser of Bottom Hole Pressure ASP from the deepest exposure or Fracture Gradient ASP at the deepest casing shoe. FG ASP Predicted Fracture Gradient = 13.5 ppg 4368 x 13.5 x 0.052 = 3066 psig. Correcting for gas gradient 3066 - (4368 x 0.10) = 2630 psig Therefore, FG ASP = 2630 psig BHP ASP Depth of next hole section = 4368' TVD. Mud wt at TD = 9.8 ppg. Maximum predicted pore pressure at TD = 9.3 ppg. Pressure of gas column 0.7 x 6343 x 0.10 = 444 psig Pressure of mud column -* 0.3 x 6343 x 9.8 x 0.052 = 970 psig Pore pressure = 6343 x 9.3 x 0.052 = 3067 psig Chevron Steelhead Platform Well M -17 Drilling Program 2007 Therefore, BHP ASP = 3067 - 970 - 444 = 1653 psig MASP = 1653 psig • Notes: 1 FG ASP calculations assume an evacuated wellbore. 2 BHP ASP calculations assume a 70% evacuated wellbore and 30% mud column. 40 • • Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Note that the terms used in the procedures and the spreadsheet of FIT /LOT results are defined as follows: • Formation Integrity Test (FIT) - Formation is tested to a pre- determined equivalent mud weight. • Leak -Off Test (LOT) - Pressure is exerted against the formation until fluid begins to discernibly pump away. Pressure at which this first occurs is the leak -off point. • LOT Limit - 16.0 ppg EMW for all surface casing shoe tests; determined from previous experience with formation breakdown problems by attempting higher leak -offs. • Open Hole LOTs (OH LOTs)- Leak -off tests performed with open hole from the casing shoe to some point above the target reservoir. Generally done when leak -off is required but could not be achieved just below the casing shoe; or where weaker formations are suspected above the target reservoir but below the casing shoe, and assurance is required of being able to achieve estimated mud weight. Procedure for FIT: 1. Drill 20' of new hole below the casing shoe. 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drillpipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1- minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre- determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Formation integrity tests are conducted on all casing shoes with the exception of some surface casing situations. Where annular pumping will be done on a well, the formation below the surface shoe is taken to leak -off. This ensures that future disposal fluids can pumped away without risk of damage to the surface shoe. If two attempts at establishing leak -off at the shoe are unsuccessful (using 16.0 ppg EMW LOT limit per definition above), then an open -hole LOT is performed. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre- determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Chevron fir 1/40. C hevron BAKER Location: Cook Inlet, Alaska (Offshore) Slot: slot #A1 -9 HUGH Mil. F ield: McArthur River Field Well: M-17 BAKER Facility: STEELHEAD Platform Wellbore: M -17 Scale 1 inch =20rt Easting (ft) -70 -80 -50 -40 -30 -20 -10 0 10 20 30 40 50 60 280 rt 10 wil 1600 00�'tr 0 140 A �� 20., 8001600 800 260002200 — 50 800 80' ■ 40 5800 2000 20 slot #A1 - °slot #A1 -4 — 10 slot #A1 -1 slot #A1-1 1 slot #A1 • A el 5600 slot ' 1 -: 800 a o A 800 — 0 1000 1 1 2'4400 100' 40' 800 2600 — -10 2800 1800 1000 800 Z - -20 0 1200 1000 to 1201 x 1601 — -30 1400 3000 td 1n• I - -40 6400 — -50 1200 — -60 1200 — - 70 1200 6200 Q - -90 a � ® i t Plot reference wellpath is M -17 Version #5 True vertical depths are referenced to Actual Datum (RKB) Grid System: NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Actual Datum (RKB) North Reference: True north Actual Datum (RKB) to mean sea level: 160.25 feet Scale: True distance mean sea level to Mud line (Facility - STEELHEAD Platform): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: jonethoh on 29- Aug -07 Chevron I gni 101001 C hevron BAKER ftio L ocation: Cook Inlet, Alaska (Offshore) Slot: slot #A1 -9 INTEQ Field: M R iver F We ll: M -17 Facility: STEELHEAD Platform Wellbore: M -17 s a , soft Easting (ft) -175 -150 -125 -100 -75 -50 -25 0 25 50 75 100 125 150 175 1 1 1 1 1 1111 Ir I I 1500 1100 200 1 1200 1200 3100 .9 — - 75 1200 1300 6200 1300 1300 — -100 1400 1300 00 3200 — 1500 9 - /8 Csg Intermediate: L -125 1400 141 1400 — -1550 1600 ® 6300 — - 175 1700 1500. 3300 6600 — -200 1800 6400 — - 225 1600 Z 0 a 1900 — -250 3 6700 t0 ."S 3400 — -275 2000 1700 6' u — -300 6800 — - 325 2100 — -350 1800 6600 — - 375 6900 3500 — - 400 2200 C - 425 6708 190w. ® — -450 Plot reference wellpath is M -17 Version #5 True vertical depths are referenced to Actual Datum (RKB) Grid System: NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Actual Datum (RKB) North Reference: True north Actual Datum (RKB) to mean sea level: 160.25 feet Scale: True distance mean sea level to Mud line (Facility - STEELHEAD Platform): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: jonethoh on 29- Aug -07 Chevr I /ar Chevron BAKER Nu6NEs Location: Cook Inlet, Alaska (Offshore) Slot: slot #A1 -9 INTEQ Field: McArthur River Field Well: M -17 Facility: STEELHEAD Platform Wellbore: M -17 sw 50R Easting (ft) -225 -200 -175 -150 -125 -100 -75 -50 -25 0 25 50 75 100 125 I 6900 350$ -000 2200 - 425 1900 - 450 7000 - 475 2300 -500 -525 2000 7100 - 550 2400 -575 Z 0 S -60o 7200 - 625 2100 -650 -675 7300 -700 -725 2200 - 750 7400 8 -775 Plot reference wellpath is M - 17 Version #5 True vertical depths are referenced to Actual Datum (RKB) Grid System: NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Actual Datum (RKB) North Reference: True north Actual Datum (RKB) to mean sea level: 160.25 feet Scale: True distance mean sea level to Mud line (Facility - STEELHEAD Platform): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: jonethoh on 29- Aug -07 0 • Chevron MIMI Chevron U�H ES Location: Cook Inlet, Alaska (Offshore) Slot: slot #A1 -9 INTEQ F ield: McArthur River Field Well: M -17 Facility: STEELHEAD Platform Wellbore: M -17 1 IMMO Easting (ft) Scale i incn = 100 rt -500 -450 -400 -350 -300 -250 - 200 - 150 - 100 - 0 50 100 150 200 1 I I I I I , I I I I I I I 860 7300 — -700 8700 8800 2200 — -750 2600 7400 890' — -800 9000 — -850 7500 9100 2700 2300 — -900 9200 700 8600 9300 7600 — -950 8800 8700 2800 9400 8900 Z 9500 o 2400 7700 -1050 S 9000 �� 8800 ` co 9600 9100 — - 1100 9700 2900 7800 8900 9200 9800 — -1150 0. •500 9300 ,o — -1200 •III 7900 3000 9400 6■ - 1250 ti c 9100 9500 800G - 1300 2600 — -1350 3100 9200 9600 81 I 8 0 — -1400 9700 93000 Plot reference wellpath is M -17 Version #5 True vertical depths are referenced to Actual Datum (RKB) Grid System: NAD27 / TM Alaska State Plane, Zone 4 (5004), US feet Measured depths are referenced to Actual Datum (RKB) North Reference: True north Actual Datum (RKB) to mean sea level: 180.25 feet Scale: True distance mean sea level to Mud line (Facility - STEELHEAD Platform): 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by: jonethoh on 29- Aug -07 • • Chevron Ch evron BA KER • %Oi Location: Cook Inlet, Alaska (Offshore) Slot: slot #A1 -9 HUGHES F ield: McArthur River Field Well: M -17 INTEQ Facility: STEELHEAD Platform Wellbore: M -17 �m= It (ft) -1300 -1200 -1100 -1000 -900 -800 -700 -600 -500 -400 -300 -200 -100 0 100 200 1 1 1 1 1' I I f 1 290017 I 1 I I 1 7800 9600 8900 9200 7900 9800 9700 9000 9300 C "'� 02 -1200 8000 3000 9400 8100 9100 9500 8000 ' - 1300 2600 8200 3100 9200 9600 8100 8300 \ -1400 2700 9300 9700 8400 3200 9400 4 - 1500 8500 2800 8600 9500 3300 -1600 8700 2900 9600 8800 3000 - 1700 3400 9700 8900 8900 3100 9000 9000 - 1800 3500 3200 9100 9100 3_1_00 M17 Tgt B 83(19- Sep -06) - 1900 9200 3400 9200 3600 Z 9300 -2000 3 w 3 3 co 9300 9400 3600 3700 -2100 9400 9500 3700 9600 3800 •2200 9500 3800 9700 3900 M17 Tgt C C1 (19 Sep - 06) 9600 9800 4000 -2300 3900 4100 IP 9900 O , 9700 4204 10400 -2400 0.4 10300 •000 10200 '300 1010 -2500 1000. 4500 4100 1 9900 -2800 9800: 4600 9700 ,, a 7" Csg Intermediate: 4700: - 2700 / • 4200 M17 Tgt 0 D3B (19- Sep -06 9600 ' l r 4800 9500 8 9 00 uu 4900 -2800 9400 P 43 M17 Tgt E D6 (19 Sep - 06) a '1 9300 O "P" 8800 5000 O „el -2900 3 0 • Chevron Chevron BA Milli Location: Cook Inlet, Alaska (Offshore) SIOt: slot #A1 - HUGHES Field: McArthur River Field Well: M -17 INTEQ Facility: STEELHEAD Platform Wellbore: M -17 Swat/ = R Easting (ft) -1500 -1400 -1300 -1200 -1100 -1000 -900 -800 -700 -600 -500 -400 -300 -200 -100 9500 X1 — -2800 4900 9401 1' 4300 r M17 Tgt E D6 (19- Sep -06) a 2 9301 O'SO� 8800 5000 - - 2900 4 9200 8900 9201 9900 9101 8700 4400 9:, 5200 `, — -3000 9101 r 6 9000 8801 9700 5300 8900 9011 8600 4500 9600 . 5400 — -3100 870. 890. 9500 5500 8811 9301 1.., 9400 — -3200 3711 4600 5600 920. 9300 9101 Rd ZG 9200 5700 0-50 9001 900, — -3300 8600 9 00 :00 4700 8901 9000 5900 8801 — -3400 8900 6000 8700 8800 4800 Z 8611 6100 - - 3500 a 8700 S 8501 — M17 FF to 8600 8401 6200 8500 4900 — -3600 8311 6301 8400 _ M17 T ', ^ ♦ Tgt G TO 820 8300 8101 — -3700 8200 5000 8100 8011 8000 7900 — -3800 7800 5100 — -3900 5200 — -4000 5300 — -4100 5400 - -4200 5501 • 111 TRANSMITTAL LL L ETTER � CHECKLIST WELL NAME "1 - 04 '/ " / 7 PTD# 2.07- /2Z /Development Service Exploratory Stratigraphic Test Non - Conventional Well Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore 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(0, 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. Please note the following special condition of this permit: Non - Conventional production or production testing of coal bed methane is not allowed Well 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: 7/13/2007 Field & Pool MCARTHUR RIVER, MIDKENAI GAS 520550 y. „ - Well Name: TRADING BAY UNIT M -17 Program DEV Well bore seg ❑ PTD #:2071200 Company UNION OIL CO OF CALIFORNIA Initial Class/Type DEV / PEND GeoArea 820 Unit 12070 On /Off Shore On Annular Disposal Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Surface location in ADL 18730; top prod interval and TD in ADL 17594. 1 3 Unique well name and number Yes 4 Well located in a defined pool Yes MCARTHUR RIVER, MIDKENAI GAS - 520550, governed by CO 228. 5 Well located proper distance from drilling unit boundary Yes Rule 1 of CO 228 established 10 -acre drilling units for the Middle Kenai Gas Pool at the mid -point of the pool 16 Well located proper distance from other wells Yes which is the D -1 sand because of the lenticular nature of the fluvial . reservoir sands. 7 Sufficient acreage available in drilling unit Yes !8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes ■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 9/13/2020 .13 Can permit be approved before 15 -day wait Yes !14 Well located within area and strata authorized by Injection Order # (put 10# in_comments) (For NA 1 Il 5 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),(j.2.A -D) NA Engineering .18 Conductor string provided Yes 19 Surface casing protects all known USDWS NA All aquifers exempted, 40 CFR 147.102 (b)(2)(iv). 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg Yes 22 CMT will cover all known productive horizons Yes 123 Casing designs adequate for C, T, B & permafrost Yes !24 Adequate tankage or reserve pit Yes Existing rig. Mud and cuttings to be disposed per NPDES discharge permit. 25 If a re- drill, has a 1.0 -403 for abandonment been approved _ NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Close approaches identified. Wellbore presure monitoring proposed. 27 If_diverter required, does it meet regulations Yes Request to drill 17 -1/2" hole with 16" diverter lines. Request has been approved previously. Appr Date 128 Drilling fluid program schematic & equip list adequate Yes Maximum expected formation pressure 9.3 EMW. Due to depleted pressures, planned mud weight 9.2 ppg or as TEM 9/24/2007 '.29 BOPEs, do they meet regulation Yes ,�,��,N/�\ ; BOPE press rating appropriate; test to (put psig in comments) Yes MASP calculated at 1654 psi. Planned BOP test pressure 4000 psi. •„,-. „ 31 Chok manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No H2S not reported in gas production, however present in oil. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA Geology 35 Permit can be issued w/o hydrogen sulfide measures No Steelhead Platform is a designated H2S site. 36 Data presented on potential overpressure zones Yes Reservoirs are expected to be underpressured. The mud program calls for 9.1 to 9.2 ppg mud. Precautions are Appr Date 37 Seismic analysis . of shallow gas zones NA discussed in the Summary of Drilling Hazards. SFD 9/5/2007 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Ge•logic Engineering P •lic SPACING EXCEPTION NOT NEEDED: the Grayling Gas Sands are equivalent to the Middle Kenai Gas Pool, as defined in • s•' er: Date: Date Date y g q Ai uer o missioner. ate . ` CO 228 and expanded vertically by CO 228.2. Rule 1 of CO 228 established 10 -acre drilling units for the Middle Kenai Gas �d // Ii /i � // �) Pool at the mid -point of the pool, which is the D -1 sand. The clear intent of the order is to establish 10 -acre spacing because / 4 / c/(4' v of the lenticular nature of the fluvial reservoir sands. The nearest gas well is TBU M -14RD, which is located 975' NE. This well conforms to the 10 -acre soacina requirements of CO 228 ito?5/d7' 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 IWO %OOP M -17 Platform Steelhead Trading Bay Unit Upper Cook Inlet, Alaska SEC 33 T9N R13W SM October 27, 2007 — December 5, 2007 4 ss'-i ,yes ft • A Lees F. Browne Jr: Senior Logging Geologist Harry Bleys: Logging Geologist Craig Silva: Senior Logging Geologist Li EPOCH • ao -- 7 , la° 1s,2 Chevron CHEVRON M -17 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT AND CREW 2 1.1. EQUIPMENT SUMMARY 2 1.2. PERSONNEL 2 2. GENERAL WELL DETAILS 3 2.1. OBJECTIVES 3 2.2. WELL RESUME 3 2.3. HOLE DATA 3 3. GEOLOGICAL DATA 4 3.1. LITHOLOGY REVIEW 4 3.2. SAMPLING PROGRAM AND DISTRIBUTION 17 4. DRILLING DATA 18 4.1. DAILY ACTIVITY SUMMARY 18 4.2. SURVEY RECORD 21 4.3. MUD RECORD 25 . 4.4. BIT RECORD 26 4.5. DRILLING PROGRESS CHART 27 DAILY REPORTS APPENDIX I FORMATION LOGS APPENDIX II DRILLING DYNAMICS LOGS APPENDIX III El EPOCH Chevron CHEVRON M -17 • 1 MUDLOGGING EQUIPMENT AND CREW 1.1. EQUIPMENT SUMMARY Parameter Equipment Type And Position Total Comments Downtime QGM Style Trap Mounted In Possum Ditch Gas Belly; FID Total Hydrocarbon Analyzer 0 And Chromatograph Rate of Penetration (ROP) All Data From Totco WITS Feed n/a Pump stroke counters All Data From Totco WITS Feed n/a Hookload / Weight on bit (WOB) All Data From Totco WITS Feed n/a Drill string torque All Data From Totco WITS Feed n/a Top drive rotary (RPM) All Data From Totco WITS Feed n/a Standpipe Pressure All Data From Totco WITS Feed n/a Mud flow in / out (MFI / MFO) All Data From Totco WITS Feed n/a Pit volumes All Data From Totco WITS Feed n/a Driller's work station N/A Casing Pressure All Data From Totco WITS Feed n/a Company man's work station N/A Mud Engineer's work station N/A Living quarter's work station N/A Pit's work station N/A 1.2. PERSONNEL Unit Number: ML004 M -17 Mudloggers Years Days s at Catchers/ Days s Technician Days s Experience well Trainees well well Lees Browne 26 29 + Dickey Hudgins 4 Steve Forrest 6 Harry Bleys 4 11/06 James Feradas 3 Craig Silva 29 19 EPOCH 2 Chevron CHEVRON M -17 2. GENERAL WELL DETAILS • 2.1. OBJECTIVES The objective of M -17, a Development Gas well in the Grayling Gas Sands (Tyonek Formation) of the McArthur River Field, is to develop additional gas reserves and deliverability and to test for reservoir compartmentalization caused by faulting. This grassroots well, an infill gas well updip of Well M -15, will have as primary targets, the D16ABC, D14, D -6, D3B and C5 zones within the GGS. After successfully drilling M -17 with a minimum of hole problems and other contingencies, a standard completion will be performed. This project will hopefully result in the promotion of P2 and P5 reserves to P1. 2.2. WELL RESUME Operator: CHEVRON (Union Oil Company of California Well Name: M -17 Field: McArthur River Field (Tyonek Interval, Grayling Gas Sands) County: Kenai Peninsula Borough State: Alaska Company Representatives: Shane Hauck Steve Lawrence Ray Vaussine Dave Smith John Raney Location: 1052' FNL, 455' FWL, Sec 33 T33N R9N SM, X= 214,070.000, Y= 2,499,450.00 Classification: Development Oil API #: 50 — 733 — 20552 — 00 Permit*: 207 - 120 Activity Code: (WBS #s) M -17 UWDAK- D7001 -DRL Name / Type: Steelhead Platform / Triple vation: Ground, RKB 160.25' AMSL Primary Targets: / Target Depths: C5: 5147'Mo 4188.95'Tvo D3B: 5834'Mo 4785.38'Tvo D6: 6174'Mo 5082.11'TVo Primary Targets: / Target Depths: D14: 7140'Mo 5917.19'Tvo D16ABC: 7362'Mo 6109.26'Tvo Spud Date: September 27, 2007 Total Depth 7670' Total Depth Formation: Tyonek Total Depth Date: November 16, 2007 MWD Companies: / Tools Run: Baker Hughes Inteq: Directional /MWD Scientific Drilling: Directional /Gyro Directional Drilling: Baker Hughes Inteq Drilling Fluids Company: M -I Drilling Fluids 2.3. HOLE DATA M17 Hole Maximum Depth T.D. Mud Deviation Shoe Depth _ F.I.T. Section MD SSTVD Formation Wei ( °inc) Casing MD SSTVD EMW (pp9) 17 %" 903' 742.60' Tyonek 9.3 3.00 13 %" 895' 734.61' 12.8 12 %4" 1435' 1248.05' Tyonek 9.3 26.22 9 %" 1430' 1243.58' 12.8 8 '/" 5710' 4517.56' Tyonek 9.15 30.05 7" 5700' 4508.89' 13.5 6 1/4" 7670' 6219.42' Tyonek 9.2 28.03 5" xxxx'- xxxx.xx' Standard Liner xxxx' xxxx.xx' Completion El EPOCH 3 Chevron CHEVRON M -17 3. GEOLOGICAL DATA • 3.1. LITHOLOGY REVIEW Tuffaceous Claystone/Tuffaceous Siltstone (700' -900') = nearly all clays and silts derived from redeposited volcanic ash; both massive and thinly bedded occurrence; note that tuffaceous claystone is very pervasive supporting matrix material of sandstone; light grayish brown to medium light gray overall, but note many subtle variations of gray and brown colors and secondary hues; soft to slightly firm; soluble, hydrophilic; poor to good adhesiveness, poor to moderate cohesiveness; often has high content of shards /microshards, and locally transitions to less reworked "cleaner- looking" and more texturally homogeneous volcanic ash; clayey to ashy to silty to various soft matte textures; earthy to partial microsparkly lustres; often thinly interbedded with coal and other carbonaceous particles and lams. Sand /Sandstone /Conglomeratic Sand /Conglomerate (700' -900') = medium gray to medium dark gray with strong light brownish gray to brownish gray secondary hues when intergrain clay is abundant; disaggregated grains decrease lightness value to medium light gray; very fine lower to borderline granule; moderately sorted overall in fn upper to coarse lower range; very evident fining upward sands; sorting improves in localized zones; dominant angular to subangular, trace to spotty subrounded or rounded; very abundant disaggregated grains, but also abundant clay matrix supported ss; rare pieces of sandstone with calcite cementation or other support; lithic arenite to compositional graywacke; 60 -75% quartz and minor volcanic glass, trace feldspar, trace -15% cryptosilica (chalcedony, chert and various minor forms), 20 -40% diverse lithics, mafic minerals and meta - origin minerals; 75 -85% of quartz is colorless to very pale gray to very pale brown and translucent, 15 -25% of quartz and nearly all volcanic glass is colorless and transparent; very diverse group of lithics dominated by medium gray to grayish black medium grade metamorphic phyllite - argillite group rock fragments, and light green, grayish green and variegated green low grade metamorphic greenstone rock fragments; biotite and augite are discernible common mafic minerals; many other minor minerals are not readily identifiable; distinctive, • well distributed, rare grains of reddish orange volcanic rock fragments, reddish low grade jasper, greenish yellow epidote, rose quartz, pale pinkish gray quartzite, yellow citrine, colorless zircon; large conglomeratic clasts are dominated by quartz, cryptosilica, and various meta - igneous rocks. Carbonaceous Shale (720 -1063) = brownish gray mottled grayish black and various hues of both; predominantly firm occasional brittle; dull earthy luster; striated to mottled textures with local gradational matte; common subplanar to planar fracture along carbon shale partings; composed of very carbon clay, silt and shale with minor thin lignitic coals; all very gradational; trace visible bleeding gas from sublignitic coals; grading to tuffaceous clays and silt. Sand (1060 -1135) = very light gray; clast sizes range from medium upper to fine lower; subround; moderate occasional well developed sphericity; moderate sorting; polished to abraded texture; submature nature; non to very weak silic cement; dominant unconsolidated; hydrophilic clay matrix; both matrix and grain support; matrix very loosely attached; composed of predominantly quartz with minor chert, meta, greenstone and various lithic fragments; poor to fair porosity; no show of fluorescence or cut. Tuffaceous claystone (1100 -1200) = very Tight gray to pinkish gray; brittle to very soft; slightly malleable to slightly sectile; overall mushy to pasty; slightly tacky to slimy; non to very weak cohesiveness; slight to moderate adhesiveness; earthy fracture; amorphous to sub blocky to sub platy habit; moderate earthy luster; clayey texture; massive gradational silt and clay with thin to laminae carbon silts; clay is very hydrophilic and going into solution. Sand (1145 -1225) = very light gray; clast size range medium upper to fine upper; subround; moderate occasional well sorted; pitted to polished to impacted textures; sub mature to local immature nature; non to very weak silic cement; unconsolidated; hydrophilic loose clay matrix; El EPOCH 4 Chevron CHEVRON M -17 both grain and secondary matrix support; composed of predominantly quartz with minor chert, meta, greenstone and various Iithic fragments; fair porosity; no show of fluorescence or cut. Tuffaceous claystone (1225 -1300) = very light gray to pinkish gray; very soft; very slight malleable to slightly sectile; lumpy to clumpy; clustered to clotted; becoming mushy to pasty in parts; amorphous to earthy fracture; massive to subnodular habit; moderate to earthy luster; clayey to colloidal texture; massive clays with secondary carbonaceous shale and trace coal being subplanar to planar fracture. Tuffaceous claystone (1300 -1400) = very light gray; very soft; very slightly malleable to very slightly sectile; overall lumpy to clumpy; clustered to clotted; mushy to pasty in parts; amorphous to subearthy fracture; massive to subnodular habit; moderate earthy luster; clayey to colloidal textures; massive gradational clays and minor silts; thin carbon shale stringers with subplanar fracture along shale partings; some grading to sub Iignitic coal; no visible bleeding gas. Carbonaceous shale /coal = black mottled grayish black and minor reddish black and various hues of all; brittle to firm in coal; earthy to mottled resinous in coal; sub striated to matte texture in coal; sub blocky coal to sub platy shales; composed is very carbonaceous shale and Iignitic coal; visible bleeding gas from cuttings. Coal (1390 -1575) = dark gray to matte black to shiny black color; firm to brittle with ridges showing laminations; splintery fracture; tabular to wedge like cuttings habit; smooth to matte texture slightly shiny and thin to thick different hues making the coal very shiny in lower depth; gas background rising with each coal seam. Tuffaceous claystone (1400 -1500) = light gray to medium gray to a dark gray color with green and blue hues; soft to malleable to clumpy mushy; irregular fracture with soft rounded cuttings habit; washes out in solution; slightly cohesive with sand and some volcanic glass in cuttings; dull earthy to slightly shiny luster; thin to thick structure. Coal (1600 -1710) = dark gray to black with bright reflective hues; firm tough brittle tenacity; irregular to laminated to splintery fracture; wedge like tabular cuttings habit; smooth to ridged laminations to sharp edged textured cuttings; thin to thick structure; background gas rises sharply in each coal seam. Tuffaceous claystone (1500 -1600) = light gray to medium gray to dark gray with green hues and blue hues; small black carbonaceous cuttings entrained in claystone; soft malleable to tacky to clumpy mushy; irregular fracture; soft rounded to slight tabular cuttings habit; dull to waxy lust; thin to very thick structure; increasing sands entrained in tuffaceous claystone. Sand (1580 -1670) = trans to grayish white opaque dominantly quartz grains; trace green- - stone; black carbonaceous material; surface weathering as frosting and etching with rare conchodial burst; sand has green hues probably due to chlorite; unconsolidated and fairly well sorted; sub angular to sub rounded sphericity with sand mixed with ash and with volcanic glass; background gases rising moderately; R.O.P. low in sands except where more tuffaceous claystone interbeds with sands. Sand (1670 -1760) = translucent to opaque dirty white dominantly quartz grains; low to fair sorting; sub angular to rounded grains; surface abrasions of etching, frosting and rare • conchodial burst; unconsolidated sands interbedded with coal, tuffaceous claystone, and El EPOCH 5 Chevron CHEVRON M -17 carbonaceous shales grading to coal; carbonaceous shales showing abundant clay in cuttings grading to coal; sphericity low to moderate; gas moderate in sands. Coal (1745 -1860) = dark gray to black with some light gray hues; tough firm brittle tenacity; splintery to wedge like to irregular fracture; laminated to planar to platy flaky to tabular Tuffaceous claystone (1900 -2000) =; associated with rapid ROP's and sharp rise and fall of gas; interbedded with tuffaceous claystone and sand; dull to shiny luster with a thick to thin structure; visible laminations seen as ridges. Tuffaceous claystone (1700 -1900) = light gray to medium gray to dark gray with light grayish green hues; soft to malleable to clumpy tenacity; irregular fracture; soft rounded cuttings habit; dull earthy to slightly waxy luster; moderately cohesive; low to fair adhesive; hydrates quickly in water; thick structure. Sand (1850 -1950) = translucent clear grains to dirty white opaque and rare green grains; sand entrained in tuffaceous claystone and volcanic ash; tuffaceous claystone and ash hydrates quickly and washes out leaving coal and sand; fair to well sorted with fair to mod sphericity; sub angular to rounded with rare angular grains; surface abrasions of etching, and frosting. Tuffaceous claystone (1900 -2000) = light gray with greenish and grayish blue hues; soft, sectile, malleable to clumpy, mushy clotted tenacity; amorphous irregular fracture; fair cohesive to strong adhesiveness; hydrates quickly; ash, black carbonaceous material, and loose unconsolidated sands interbedded with claystone; rounded soft cuttings habit; dull to waxy to resinous luster; thick structure. Sand (1950 -2100) = clear to misty dirty white opaque with occasional green grains; well sorted grains of sub angular to sub rounded sphericity; unconsolidated with tuffaceous claystone, tuffaceous ash, volcanic glass, black carbonaceous material, coal and occasional carbon- - naceous shale; gas background levels fairly low; sand upper very fine sub rounded to rounded with fine lowers of sub angular to sub rounded sphericity with grayish green hues; gas background low to moderate; no oil or gas indicators. Sand (2100 -2235) = translucent to dirty off dusky white color; well sorted very fine uppers with fine well sorted lowers; both sub angular to sub rounded grains; low to medium sphericity; dominantly quartz with volcanic glass, ash, black carbonaceous materials, and chlorite; sands entrained in tuffaceous claystone, background gas low; no oil or gas indicators. Tuffaceous claystone (2000 -2200) = light gray to medium gray with greenish hues to dark gray with dark grayish black hues; soft mushy clumpy clotted; irregular to amorphous fracture; soft rounded clumps; non to slightly cohesive; slight adhesive; amorphous fracture; massive habit; dull earthy luster; colloidal to slightly clayey habit; massive clays becoming hydrophilic with a high content going into solution. Coal (2235 -2270) = black mottled dark gray; firm; earthy to resinous luster; matte to slightly striated texture; sub blocky fracture; composed of predominantly lignitic coal with minor very carbon shale in parts with subplanar fractures; visible bleeding gas from fresh cuttings scattered tuffaceous claystone. Sand (2275 -2380) = very light gray; clast size range from medium lower to fine upper; sub S angular to subround; moderate developed sphericity; moderate with occasional well sorted; impacted texture mature nature; non to very slight silic cement; very slight hydrophilic clay [1 EPOCH 6 Chevron CHEVRON M -17 matrix material non to loosely attached dominant grain support; fair to good estimated porosity; no show of oil fluorescence or cut. Tuffaceous claystone (2200 -2380) = very light gray to very pale orange; very soft; slightly malleable to slightly sectile; lumpy to clumpy; clustered to clotted; mushy to pasty; various consistency and tenacity; non to very slight cohesiveness; slight adhesive; amorphous fracture; massive habit; moderate earthy luster; colloidal to slight clay texture; massive gradational clays with sand and Sand (2400 -2500) = very Tight gray; clast size range from medium upper to fine upper; sub angular to subround; moderate sphericity moderate sorting; impacted texture; submature nature; non to very slight silic cement; moderate hydrophilic clay matrix; all loosely attached; both grain and matrix supported; some scattered grayish orange devitrified ash in matrix poor estimated porosity no show of oil fluorescence or cut. Tuffaceous claystone (2500 -2550) = very light gray; very soft; slightly malleable to slight sectile; various consistency + tenacity; lumpy to clumpy; clustered to clotted; mushy to pasty; non to very slight cohesiveness; slight to moderate adhesiveness; amorphous fracture and habit; massive habit; moderate earthy luster; colloidal to clayey texture; massive gradational clays and sands; visible pyroclastic relic shards in the clay matrix; overall ashy to clayey. Coal (2550 -2570) = grayish black mottled brownish black and various hues of both; overall firm; earthy with some resinous luster; matte texture; blocky to sub blocky fracture; composed of sublignitic coal to lignitic with thin laminae of very carbonaceous shale; cuttings display visible bleeding gas. • Tuffaceous claystone (2550 -2650) = light gray to very Tight gray; very soft; slightly malleable to slightly sectile; various consistency and tenacity; lumpy to clumpy; clustered to clotted; gelatin mushy clotty in parts; tacky to slimy; non to slightly cohesive; slight to moderate adhesive; amorphous fracture; massive habit; moderate to dull earthy luster; clayey to colloidal texture; massive hydrophilic ashy clay; composed of > 90% clay and ash; visible pyroclastic relic shards. Tuffaceous claystone (2650 -2710) = light gray to very light gray; very soft; slightly malleable to slightly sectile; various consistency and tenacity; lumpy to clump clustered to clotted; gelatin in part; mushy to pasty; tacky to slimy; non to slightly cohesive; slight to moderate adhesive; amorphous fracture and habit; moderate earthy luster; clayey to colloidal texture; massive hydrophilic clays becoming ashy in parts; composed of >90% clay and ash with various detrital material; visible pyroclastic relic shards in clay mass. Sand (705 -2790) = very light gray; clast size range medium upper to fine upper; sub angular to subround; moderate developed sphericity with some prolated grains; moderate sorting; pitted to impacted texture; submature to mature nature; non to very slight silic cement; unconsolidated and becoming interbeds with clay structured matrix loosely attached and very hydrophilic; matrix supported with local grain support in parts; composed of >90% quartz with minor chert, and trace meta and green stone with various lithic fragments; poor some fair porosity; no show of oil fluorescence or cut. Tuffaceous claystone (2710 -2850) = light gray to light gray with grayish white hue to occasional medium dark gray with green hues; soft mushy tacky clotted; light to moderate cohesiveness; moderate adhesiveness; irregular to amorphous fracture; soft rounded cuttings Ell EPOCH 7 Chevron CHEVRON M -17 habit; dull earthy to slight waxy luster; smooth texture; thick structure; slightly calcareous with sandstone entrained. Sand /sandstone (2800 -2900) = medium Tight gray with faint olive hues; fine upper to course lower; sub angular grains; moderately well to moderately sorted; dominantly unconsolidated sands and friable sandstones; locally hard streaks with tan slightly calcareous (ferrous) matrix and occasionally dense with calcareous cement; 70% quartz, 0 -30% accessory minerals of soft chert, volcanic glass, ash, greenstone, and lithic black carbon material; moderately visual porosity; sandstone grains companied with a rise in background gas and a reverse drill break. Coal/ carbonaceous shale (2970 -3005) = carbonaceous black hues to dark flat black to a shiny black vitreous lustrous color; firm to brittle to hard tenacity; irregular to splintery to wedge like to planar fracture; blocky to tabular to wedge- -like cuttings habit; smooth to rough ridged protruding laminae to a matte texture; dull earthy to shiny vitreous luster; visible degassing in sample solution; sharp rise and fall in back ground gases; carbonaceous shales more black with reddish hues versus coal with dark black matte to vitreous luster; carbonaceous shales shear in irregular pieces versus coals in splintery to wedge like to planar laminae. Sand /sandstone (3000 -3110) = light gray with faint Tight olive green hues and light gray with a light greenish tan color in sandstone cuttings; overall sands are unconsolidated medium course sub angular to sub rounded moderately sorted; sandstones are very fine with courser interbedded dusky reddish yellow grains; dominantly well sorted except for the interbedded grains; sandstone are firm and indurated with tight grains supported matrixes of slightly calcareous material and dominantly quartz of 60 %- 70 %, with accessory minerals of black carbonaceous material, feldspar or chert inclusions, and occasional chlorite; fair porosity; moderate rise in back ground gases. Coal/ carbonaceous shale (2960 -3173) = medium gray to medium gray with reddish hues to grayish black for carbonaceous shales; coals are medium gray to dark black to shiny vitreous black color; firm to tough tenacity with irregular fracture in carbonaceous shales and splintery to wedge like to planar fracture in coals; overall platy to tabular cuttings habit; with smooth to slight gritty texture in carbonaceous shales and smooth to ridged laminae, matte texture; dull to shiny vitreous luster; laminas in a thick to thin structure; coal accompanied with sharp rise in background gases. Tuffaceous claystone (29603220) = light gray to light gray with green to olive hues; soft mushy clotted clumpy malleable tenacity; amorphous fracture with round soft cuttings habit; dull to waxy luster; smooth clayey texture; thick structure. Sand /sandstone (3120 -3285) = light gray to Tight gray with greenish olive hues; sandstone is light gray to light gray with green olive and brown hues; unconsolidated sands with fine to medium course grains; dominantly quartz at 70% with 0 -30% of accessory minerals of feldspars, chert, calcite, volcanic glass, ash, greenstone overall sand is subangular and poorly sorted; sandstone is subangular to subrounded and moderately sorted; with fine to medium course grains; sandstone is 70 -80% quartz with 0 -20% of accessory minerals of chlorite, calcite, feldspars, black carbonaceous material; sandstone has fair visual porosity Coal (3250 -3300) = dark gray with brownish hues to a vitreous dark black; firm tough to brittle tenacity; planar to splintery fracture; tabular to planar laminae cuttings habit; dull gray to shiny • black to a vitreous shiny resinous luster; smooth to seamed ridged to a matte text; thick to thin El EPOCH 8 Chevron CHEVRON M -17 with a blocky laminated structure; background gas rises sharply with coals; visible degassing • from coal cuttings. Tuffaceous claystone (3300 -3400) = light gray to light gray with green and olive color; mushy clumped, clotted, malleable, sectile, tenacity; hydrates quickly; cohesive moderately well, adhesiveness low; volcanic glass, ash and black carbon lithics entrained in tuffaceous claystone matrix; amorphous fracture; soft irregular cuttings habit; dull earthy to waxy resinous luster; thick to thin structure. Sand (3365 -3510) = light gray to light gray with greenish olive hues; unconsolidated fair to medium course to course with angular to sub angular poorly sorted grains; dominantly quartz at 70% with accessory minerals of greenstone, feldspars, chert, calcite, carbon lithic fragments, some ash in tuffaceous claystone; gas background moderately low. Coal (3505 -3530) = dark gray with black and brown hues; hard firm brittle tenacity; planar to splintery fracture; blocky to sub blocky cuttings habit; dull, waxy to vitreous shiny luster; smooth to ridge laminae on blocky seamed surface, to matte texture; thick to thin seamed laminae planar structure; visible degassing from coal cuttings. Sand (3525 -3600) = light gray to light gray with greenish to olive green hues; course to medium course unconsolidated subangular to angular with low sphericity; poorly sorted; dominantly quartz grains at 60 - 70 %; accessory minerals of feldspar, chlorite, chert, calcite, and black carbon lithics. Sand (3600 -3705) = very light gray to light gray; clast size ranges from medium lower to fine 410 lower; subangular to subround; moderate developed sphericity; moderate occasionally well sorted; no abundant faction; impacted texture; mature nature non to very slight silic cement; loose grains /unconsolidated; non to very slight visible clay matrix; appears arenaceous; composed of >90% quartz, with minor chert, trace meta, greenstone and carbon specs; good estimated porosity; no show of oil fluorescence or cut. Tuffaceous claystone (3630 -3740) = pale yellowish brown to very Tight gray; very soft; non malleable or sectile; lumpy to clump clustered to clotted; gelatinous; slimy; amorphous fracture; massive habit; dull earthy luster; colloidal texture; massive tuffaceous clay becoming ashy in parts; very hydrophilic; interbedded with fine grained sands in parts. Sand (3740 -3830) = very light gray to light gray; clast size ranges from medium upper to fine upper with scattered coarse lower; subround; moderate with some well developed sphericity; moderate to poor sorting; pitted to polished textures; submature nature; non to very slight silic cement; moderate to abundant clay matrix content; dominant matrix support; hard to wash matrix out; hydrophilic; composed of >90% quartz, minor chert; trace various lithic fragments; poor porosity; no show of oil fluorescence or cut. Coal/ carbonaceous clay (3830 -3855) = brownish black mottled dusky brown to black and various hues of all; firm; earthy some resinous luster; matte to gritty texture scattered striated texture; dominant planar fracture; composed of very carbonaceous clay, shale and sub lignite coal; visible bleeding gas from Iignitic fragments. Sand (3845 -3910) = very light gray; clast size range from coarse lower to fine upper; sub round • occasional subangular; moderate sphericity some well developed in part; poor to moderate sorting; distinct abundant faction is medium to fine grain polished to pitted textures; submature HI EPOCH 9 Chevron IWO CHEVRON M -17 with possible mature nature in clean sands; unconsolidated with moderate clay structured matrix with both grain and matrix support loosely attached and very hydrophilic; composed of >90% quartz with various trace lithic grains; poor estimated porosity; no show of oil fluorescence or cut. Tuffaceous claystone (3910 -3980) = pale yellowish brown; very soft; slightly malleable to sectile; overall lumpy to clumpy; clustered to clotted; gelatinous; non cohesive; slight to moderate adhesive; amorphous fracture; massive habit; dull earthy luster; colloidal to ashy texture interbedded with medium grain sands; sand being thin bedded and gradational. Coal (4000 -4035) = grayish black mottled brownish black to black and various hues of all; brittle to firm; earthy to resinous luster; matte to some striated texture; sub blocky to irregular fracture; composed of very carbonaceous clay, shale and lignitic coals; visible bleeding gas from most coal cuttings. Tuffaceous claystone (4030 -4110) = pale yellowish brown; very soft; various consistency and tenacity: lumpy to clumpy; clustered to clotted; gelatinous; non cohesive to moderate adhesive; amorphous fracture; massive habit; dull earthy luster; colloidal to ashy textures; becoming interbedded with fine to medium grain sands at 4080'; dominant clay matrix support; scattered carbon fines in mass; non to very slightly calcareous. Sand (4080 -4150) = light gray to light gray with greenish olive hues; fine to course; sub angular to rounded with fair to moderate sphericity; poorly sorted; well weathered mature sands; surface abrasions of frosting, and etching; dominantly quartz at 50 -60 %; translucent to light gray opaque grains; accessory minerals of chert, calcareous tuff, ash, trace calcites, conglomerate sand, • coal, sandstones; gas background low. Tuffaceous claystone (4115 -4205) = light gray to light gray with light greenish olive hue soft mushy clotted clumpy; amorphous fracture; soft rounded cuttings habit; volcanic remnants, black carbon material loose unconsolidated sands entrained in tuffaceous claystone; dull earthy to waxy luster; smooth texture; moderate cohesive and adhesive properties; hydrates quickly; thick structure. Sand (4150 -4270) = light gray to Tight gray with greenish olive hues; medium lower to fair upper; sub angular to sub rounded well to poorly sorted; dominantly quartz at 60 - 70 %; accessory minerals of altered ash, volcanic remnants, tuffaceous claystone, volcanic glass, trace chert, trace calcite, trace chlorite, black carbonaceous lithics, conglomerate sands interbedded; individual grains translucent to Tight gray opaque color with rare orange; background gases low; no oil or gas Tuffaceous claystone (4270 -4290) = light gray to light gray with greenish olive hues; soft mushy clotted clumpy, malleable, sectile; amorphous fracture; slumped to rounded cuttings habit; dull earthy to waxy resinous luster; smooth texture; thick structure. Sand (4270 -4370) = gray to gray with green, olive an brown hues; medium to course grains; angular to sub angular; poorly to fair sorted; unconsolidated sands; clear translucent to opaque dusky white color; dominantly 50 - 70% quartz; accessory minerals of chlorite, chert, calcite, altered ash, volcanic glass, remnants of black carbonaceous lithic fragments; no oil or gas indicators. El EPOCH 10 <hevron CHEVRON M -17 Coal (4370 -4425) = dark black with brown hues and dark brown with black hues to shiny vitreous black color; firm to brittle tenacity; planar to splintery fracture; blocky to sub blocky cuttings habit ; ridged, striated texture; thick to thin laminas; visible evidence of degassing and gas background rose sharply in coal. Tuffaceous claystone (4300 -4380) = light gray to light gray with black and green olive hues; soft, malleable, clotted, clumpy sectile; amorphous fracture; rounded soft cuttings habit; smooth clayey texture; low cohesiveness and moderate adhesive properties; hydrates quickly and slumps quickly; thick structure. Sand (4270 -4370) = light gray with green olive hues and light medium gray with green olive hues; medium course to fair; angular to sub angular with low sphericity; poor to fair sorting; dominantly quartz at 80% with carbonaceous shales, conglo- - merate sandstones, chert, chlorite, carbonaceous shale, and black carbonaceous lithic fragments; translucent to opaque light gray with gray hues; light bluish green, and light tannish brown sandstone from medium to course interbedded in lower sands; visual porosity of sandstone low to moderate due to indurated tight silicic matrix; background gases low; no oil indicators. Tuffaceous claystone (4510 -4600) =gray to light gray with greenish olive hues; mushy clotted, sectile, malleable; cohesive low adhesive moderate; hydrates quickly; amorphous fracture; thick massive cuttings habit; tacky clayey smooth texture; dull earthy waxy to shiny resinous luster; massive to thick structure; Coal/ carbonaceous clay and shale (4615 -4640) = black mottled brownish black; brittle to firm; earthy to resinous luster; matte to striated textures; distinct planar fracture along very carbon shale and micro laminae of very carbon clay; composed of lignitic coal grading to very carbon shale and clay; no visible bleeding gas from cuttings. Sand (4650 -4710) = very light gray; clast size range from medium upper to fine upper; sub round; moderate some well developed sphericity; moderate sorting; impacted texture; submature to mature nature; non to very slight silic cement; unconsolidated; matrix supported and becoming grain supported by 4700'; composed of >90% quartz and trace various lithic fragments; fair to good estimated porosity; no show of oil fluorescence or oil cut. Tuffaceous claystone (4700 -4800) = pinkish gray; very soft; slight malleable to sectile; lumpy to clumpy; clustered to clotted; becoming mushy to pasty in part; non to slight cohesive; moderate adhesive; amorphous fracture; massive habit; dull earthy luster; colloidal to ashy texture massive hydrophilic clays; minor sands interbedded. Coal (4795 -4815) = black mottled brownish black; firm; overall resinous laminated earthy lustres at contacts; matte texture; irregular to sub conchoidal fractures; composed of lignitic coal with visible bleeding gas from most cuttings; very carbonaceous shale and clays at contacts. Sand (4830 -4920) = very light gray; clast size from medium lower to fine upper; subround; moderate some well developed sphericity; moderate to well sorted; impacted texture; mature nature; unconsolidated; non to very slight calcareous; dominant grain support; arenaceous; composed of 90% quartz 10% dark gray argillite, chert, greenstone; poor estimated porosity; no show of oil fluorescence or oil cut. • Tuffaceous claystone (4895 -4940) = pinkish gray to very light gray; very soft; slightly malleable to sectile; lumpy to clumpy; clustered to clotted; gelatinous; non to very slight cohesive; slight Ell EPOCH 11 Chevron I WO CHEVRON M -17 adhesive; amorphous fracture; massive habit; moderate earthy luster; colloidal to ashy texture; minor sands interbedded. Coal/ carbonaceous clay and shale (4935 -4965) = black to grayish black mottled grayish brown; firm; resinous mottled earthy lustres; matte texture; irregular fracture; composed of lignitic coals grading to very carbonaceous clays and shales; slight visible bleeding gas from coal fragments only. Sand /conglomerate sand (4975 -5115) = very light gray clast size range from coarse upper to fine upper; subangular to subround some angular bit impacted coarse grains; moderate developed sphericity; poor sorting with abundant faction of medium grains; general impacted texture; sub mature nature; non to very slight silic cement; very slight calcareous cement; slight to moderate hydrophilic clay matrix; dominant grain support with secondary matrix in parts - loosely attached; composed of 90% quartz, 10% argillite, feldspar, greenstone, black carbonaceous materials; translucent to dusky pale orange to light yellow gray opaque grains; gas background low to moderate; no oil or gas indicators. Coal (5115 -5125) = dark gray with black hues to flat black to shiny vitreous black; firm brittle hard tenacity; splintery planar fracture; blocky sub blocky cuttings habit; smooth ridged matte texture; thick to thin laminae; visible degassing; accompanied with sharp rise and fall in background gas. Tuffaceous claystone (5125 -5165) =light gray to light gray with light greenish olive hue soft mushy clotted malleable clustered with gelatinous consistency; irregular amorphous fracture; soft rounded cuttings habit ; dull to waxy to earthy lust; low cohesiveness with moderate to high adhesiveness; hydrates quickly; smooth clayey to slight grittiness with sands entrained; thick to massive structure. Sand (5140 - 5245) = light gray to light gray with greenish olive and tannish brown hues; medium to fair grain size with fair to poorly sorted conglomerate grains; angular to sub angular with low sphericity; dominantly 60 -70 % quartz accessory minerals of ash, chlorite black carbonaceous lithic fragments; unconsolidated sand with translucent to opaque dusky light yellow and pale gray; poor porosity, background gases rising slightly. Coal (5245 -5260) = dark grayish with strong black hues, flat black and shiny vitreous black with reflective hues; tough firm and brittle tenacity; seamed planar to splintery fracture; blocky to sub blocky cuttings habit; smooth to ridged edge to matte texture; thick to thin structure; visible degassing in cuttings; sharp rise and fall of background gases. Sand (5260 -5350) = light gray to light gray with light greenish olive and light brown dominantly medium with fines and course grains throughout; sub angular to sub rounded grains, some rounded well worked grains; low to poorly sorted unconsolidated sands of low porosity dominantly quartz at 60 -70% with accessory minerals of chlorite, black carbonaceous lithics. Sand /conglomerate sand (5350 -5415) = light gray to light gray with olive and brown hues; grains sizes vary from course upper to fine upper; angular to sub angular to sub rounded grains with surface abrasion of impact evidence of frosting, etching and rare conchodial burst; poor sorting; dominantly unconsolidated sands with some sandstones; dominantly quartz at 70 -80% with 0 -20% of chert, chlorite, black carbonaceous lithic fragments, trace altered ash, and trace • volcanic glass; individual grains appear translucent to pale yellow and pale light gray opaque; porosity moderate; with no signs of oil or gas indicators. L EPOCH 12 Chevron CHEVRON M -17 41 Tuffaceous claystone (5415 -5500) =light gray to light gray with greenish olive and brown hues; soft clotted clumped sectile malleable; amorphous fracture; soft rounded cuttings habit; dull earthy waxy luster; smooth clayey texture; massive structure; black carbonaceous lithics and loose sands entrained. Sand (5290 -5590) = light gray to light gray with greenish olive and light brown hues; medium and course sized quartz grains; sub angular to sub rounded grains; low to poorly sorted unconsolidated sands; dominantly quartz at 60 -70% with 0 -30% of altered ash, black carbonaceous lithic fragments, chlorite, feldspars, calcites and volcanic fragments; single grains are translucent to pale yellow and pale gray hues; feldspars are pale Tight orange, ash is tannish brown, and conglomerate sands; sphericity low; porosity low; moderate; gas background low; no oil or gas indicators. Coal (5585 -5625) = dark gray with black and brown hues to dark black to vitreous black color; firm hard brittle tenacity; planar to splintery fracture; blocky to sub blocky cuttings habit; smooth to ridged laminae; thick to thin to massive structure; visible degassing in sample; coals accompanied with sharp rise and fall of coal gas. Tuffaceous claystone (5625 -5710) = light gray to light gray with pale gray to light olive hue; mushy clotted gelatinous and sectile malleable consistency; amorphous fracture; soft rounded cuttings habit; smooth clayey texture; dull earthy waxy luster; massive structure; slightly calcareous; hydrates quickly; cohesiveness poor; adhesiveness low. • Coal (5750'- 5820') = massive sections; black to brownish black to very dusky brown; mostly high grade lignite, but ranges from lowest grade lignite that is thinly interbedded /inter laminated with carbonaceous shale to "shinier" sub bituminous and possibly bituminous; smooth to very dense matte texture; dull to "pressed" earthy to resinous and vitreous lustres; mostly thin irregular to platy cuttings habit that becomes blockier as grade improves; can become fragmented to smaller "coffee ground" size, and occasionally also splintery; dominant platy to irregular fracture, minor blocky fracture, rare birds eye fracture; these coals distinguished by dense microthin alternating laminations of different coal grades; occasional fractures filled with calcite or silica; abundant outgassing. Tuffaceous sandstone /sandstone /sand (5790'- 6050') = abundant and locally pervasive sandstones supported by volcanic ash - derived claystone with abundant glass shards (winnowed from reworked ash) that "float" within the intergrain clay; note high percentage of matrix volume that locally grades to very sandy tuffaceous claystone; also observe that with higher gas the matrix volume will decrease significantly, grains will easily disaggregate and spots of weak calcite cement will be present; very light gray to light medium gray, with faint yellowish gray and brownish gray secondary hues; note salt and pepper appearance when clay percentage is low; very fine lower to spotty coarse lower; moderately sorted in fine lower to medium lower range; inconsistent fining upward; note very fine fraction is strongly dominated by glass shards from reworked ash; sorting improves in localized zones; dominantly angular - discoidal to subangular- sub discoidal but some "clean" sand with common subrounded -sub spherical. Tuffaceous sandstone /sandstone /sand (5790'- 6050') = note rare to spotty pieces of grain supported sandstone with calcite (and /or silica) cementation, and also spotty sandstone with mixed support from combinations of ash, clay, devitrified ash, minor silt, crystalline and powdery forms of calcite and silica, and tiny concentrations of shards; sub lithic arenite to lithics arenite; EPOCH 13 Chev CHEVRON M -17 locally marginal compositional graywacke; 60 -85% quartz and minor volcanic glass, trace • feldspar, 10 -15% cryptosilica (chalcedony,chert, various minor forms), 20 -30% fairly diverse lithics and mafic minerals; lithics dominated by medium dark gray to grayish black medium grade meta phyllite - argillite rock fragments and lesser Tight green to grayish green to variegated green low grade meta greenstone rock fragments. tuffaceous claystone /volcanic ash (5730'- 6200') = abundant clay and silt derived from reworked and redeposited volcanic ash; both massive and thinly bedded occurrence; tuffaceous clay and less reworked volcanic ash are support matrix material of sandstone; light grayish brown to medium light gray overall, but note many subtle variations of gray and brown colors and secondary hues; soft to slightly firm; soluble, hydrophilic; poor to good adhesiveness, poor to moderate cohesiveness; general high content of shards /microshards; some tuffaceous clays have very few "floating" sand grains and a homogenous overall appearance; clayey to ashy to silty to various soft matte textures; earthy to partial microsparkly lustres; locally interbedded with coal or other carbonaceous particles and laminations. Tuffaceous sandstone /sandstone /sand (6050'- 6350') = continued dominance of sandstones supported by tuffaceous claystones, but support is becoming increasingly mixed overall; note significant intergrain carbonaceous material in some sandstone, especially when adjacent to coals; clastic coal fragments are locally abundant; continue to observe spotty pieces of sandstone that are grain supported, appear to be supported by weak calcite or silica cementation and have fewer intergrain shards; very light gray to light medium gray, with faint yellowish gray and brownish gray secondary hues; continued salt and pepper appearance when clay percentage is low; very fine lower to trace coarse lower; moderately sorted in fine lower to medium lower range; subtle fining upward; note very fine fraction is nearly all glass and glass • shards winnowed from ash; sorting improves in localized zones; dominantly angular - discoidal to subrounded -sub spherical; continued traces of sandstone with intergrain mix of tuffaceous clays and calcite; sub lithic arenite to lithics arenite to marginal compositional graywacke; 60 -80% quartz and minor volcanic glass, trace feldspar, 10 -15% cryptosilica (chalcedony,chert, various minor forms), 15 -30% moderately diverse lithics and mafic minerals; augite and biotite are discernible; most mafic minerals not readily identifiable in cuttings, but obviously several different dark gray to blackish translucent to opaque minerals; continued dominant lithics are dark gray to grayish black medium grade meta phyllite - argillite rock fragment and light green to grayish green to variegated green low grade meta greenstone rock fragments; note distinctive traces of orange red low grade jasper, greenish yellow epidote, rose quartz, colorless zircon. Coal (5820'- 6540') = continued massive zones distinguished by dense microthin alternating laminations of different grades of coal; note coals overall are shifting to a higher grade and generally becoming harder and less brittle; black to brownish black to very dusky brown; dominant high grade lignite and range from low grade lignite with thin interbeds /interlaminations of carbonaceous shale to very "shiny" lower grade bituminous; smooth to very dense matte texture; dull to resinous lustre; often sub vitreous to vitreous; very abundant thin irregular to platy cuttings habit; high grades of blocky; locally common "coffee ground" size fragments; occasionally splintery; dominant platy to irregular fracture, minor blocky fracture, rare birds eye fracture; local calcite or silica filled fracture; note rare but distinctive yellowish resinite (amber); slight to vigorous outgassing. Tuffaceous claystone /volcanic ash (6200'- 6700') = continued abundant clays derived from reworked and redeposited volcanic ash; both massive and thinly bedded; tuffaceous clay and • the less reworked volcanic ash are supporting matrix material of the sandstones; Tight grayish brown to medium light gray overall, but also many subtle variations of gray and brown colors El EPOCH 14 Chevron CHEVRON M -17 and secondary hues; soft to slightly firm; soluble, hydrophilic; poor to good adhesiveness, poor • to moderate cohesiveness; general high content of shards /microshards; some tuffaceous clays have very few "floating" sand grains and a homogenous overall appearance; clayey to ashy to silty to various soft matte textures; earthy to partial microsparkly Iustres; locally interbedded with coal or other carbonaceous particles and laminations. Sand /sandstone /tuffaceous sandstone (6350'- 6850') = continued dominance of sandstones supported by tuffaceous clays and ash , but significant overall decrease in matrix clay and ash and disaggregated sand generally appears "cleaner" and less colored by the clay and carbonaceous material; note that Iithic fragments decrease overall; continued spotty pieces of sandstone that are grain supported, appear to be supported by weak calcite or silica cementation and have fewer intergrain shards; very light gray to Tight medium gray; secondary hues are a very faint very light greenish gray; increased salt and pepper appearance with lower clay percentage; very fine lower to trace coarse lower; moderately sorted in fine lower to medium lower range; subtle fining upward; note very fine fraction is nearly all glass and glass shards winnowed from ash; sorting improves in localized zones; dominantly angular - discoidal to subrounded -sub spherical; continued traces of sandstone with intergrain mix of tuffaceous clays and calcite. Sand /sandstone /tuffaceous sandstone (6350'- 6850') = sub Iithic arenite to Iithic arenite; trace compositional graywacke and trace lithic quart arenite 60 -90% quartz and minor volcanic glass, trace feldspar, tr -15% cryptosilica (chalcedony,chert, various minor forms), 10 -25% moderately diverse lithics and mafic minerals; augite and biotite are discernible; most mafic not readily identifiable but various dark gray to blackish translucent to opaque minerals; continued dominant lithics are dark gray to grayish black medium grade meta phyllite - argillite rock • fragment and light green to grayish green to variegated green low grade meta greenstone rock fragments; note distinctive traces of orange red low grade jasper, greenish yellow epidote, rose quartz, colorless zircon; note increased percentage of colorless and transparent quartz (and glass) grains. Sand/ sandstone (6970 -7050) = light gray to Tight gray with pale gray with Tight olive hues; large amounts of ash mixed in sand, sandstone samples; great amount of coal sluffing down hole; upper and lover moderate with rare upper fines mostly from reworked ash and loose quartz; angular to sub angular to sub rounded grains both loose unconsolidated sands and sandstones; fair to poor sorting in loose unconsolidated sands; better sorting in grain supported ss with tuffaceous claystone and ash matrix; dominantly quartz at 60% with chert, volcanic glass, trace chlorite; individual grains clear translucent to dirty Tight gray to a frosted grain showing evidence of surface abrasions including etching; low visual porosity gases rising slowly with tuffaceous claystone interbedded in sand. Tuffaceous claystone (7080 -7200) = light gray with light gray with pale gray and yellow and greenish olive hues; mixed greatly with ash and coals falling in hole from above, ash reworked creating a soft clumpy clotty malleable to slight firm hydrophilic consistency; amorphous fracture; slumped soft round indeterminant cuttings habit; poor to slightly higher adhesive to same cohesiveness; smooth to gritty texture with large amounts of volcanic glass, interbedded coal and loose unconsolidated sands; dull waxy to sparkle with entrained quartz and volcanic glass; thick to very massive structure. Sand ( 7140 -7250 ) = Tight gray with bluish hues to soft pale gray to Tight gray with greenish • olive and pale yellow gray hues; medium lower and course upper sand grains; immature worked angular to more mature sub angular to sub rounded to rounded grains, possibly due to reworked El EPOCH 15 Chevron CHEVRON M -17 volcanic glass; poorly to fair sorted loose unconsolidated sands; dominantly quartz 70% with accessory minerals of calcite, trace chlorite, chert, abundant black carbonaceous lithic fragments, volcanic reworked glass, tuff and ash clear to Tight pale gray to gray with pale yellow and light brown hues; opaque pale gray to a opaque frosted grains; abundant Tight gray tuffaceous claystone interbedded with sands; thin to thick massive structure; moderate visual porosity; interbedded in tuffaceous claystone. Sand /sandstone /tuffaceous sandstone ( 7290- 7400 ) = light gray to gray with pale gray , yellow and Tight brown hues; well sorted from fine upper tuffaceous sandstones; poorly sorted sands of lower medium to lower course; sandstone of lower medium course well sorted grain supported cuttings; sub angular to sub rounded to rounded; predominantly quartz at 70 %, with volcanic glass shards and rounded reworked volcanic glass, trace chlorite, abundant ash, chert, feldspars and abundant black carbonaceous lithic fragments 9 ments fallin from above; black coal fragment not degassing; dominant quartz translucent to a pale gray with yellow or blue or Tight brown hues to opaque pale gray with surface abrasions of frosting or etching; dominantly well weathered and worked grains; upper sands interbedded with tuffaceous claystones, and in the middle some coal seams; gas rising slowly in sands, sandstone and tuffaceous sandstone. Sand /sandstone (7400- 7532)= light gray to light gray with greenish olive and light pale yellow and brown hues; grains in loose unconsolidated sands ranging for upper depth with upper medium to lower course and some low fines: closer to 7500 ft sands upper fn to upper medium to lower very course grains; poorly sorted through out range with dominantly sub rounded to rounded and some sub angular grains; dominantly sandstone in trace amounts of lower grain supported medium size; sandstone sub angular to sub rounded; well sorted grains through range of depth; sand and sandstone dominantly quartz of 70 - 80 %, accessory minerals of • chert, tuffaceous claystone, trace tuffaceous sandstone, trace chlorite, volcanic reworked glass, ash and black carbonaceous lithic fragments sluffing for above; gas moderately as high as 428 units. Sand /sandstone (7542 -7670) = light gray to light gray with light pale yellow light brown hues; grain size poorly sorted at lower course to upper fine: sub rounded to rounded with occasional sub angular grains; sandstone grain supported upper fines to lower medium grains size; dominantly sub rounded and well sorted; both sand and sandstone dominantly quartz of 60 - 70%, accessory minerals of tuffaceous claystone, trace chlorite, trace chert, carbonaceous black lithic fragments, ash and volcanic glass; quartz grains translucent to pale grayish yellow, blue, green, Tight brown and with surface abrasions of frosting, etching and trace conchodial burst; gas background moderate with no oil or gas indicators. • [I EPOCH 16 Chevron CHEVRON M -17 • 3.2. SAMPLING PROGRAM AND DISTRIBUTION M -17 Set Type and Purpose Interval Frequency Distribution Chevron North America E &P Washed and Dried 50' Attn: Debra Oudean A 903' —7670' Intervals 909 W. 9 Ave. Anchorage, AK. 99501 -3322 Chevron North America E &P Attn: Debra Oudean B 50' Washed and Dried 903' — 7670' Intervals 909 W. 9th Ave. Anchorage, AK. 99501 -3322 • • El EPOCH 17 Chevron CHEVRON M -17 4. DRILLING DATA • 4.1. DAILY ACTIVITY SUMMARY 10/28/07: Commence logging at 485' at 6 AM on 10/27/07. Drill formation to 903' while taking Gyro Surveys every 50'. Circulated the hole clean and pulled out of the hole to make up casing washing tool. 10/29/2007: Pulled out of the hole and lay down smart tools and pick up casing wash tool. Trip in the hole and wash to bottom. Maximum Trip Gas was 90 units. Pull out of the hole and lay down the wash tool and rig up to run 13 3/8" casing. Run 13 3/8" casing to the landing joint and rig up to cement. 10/30/2007: Began cement job and pumped the "mud push ". The "mud push" was halted due to the loss of fluid in Pit #7. Mud lines were traced and two valves were replaced in the pump room. A metal nut on a rope was added to every pit and a new pit volume spread sheet was generated. Water flowed into the cement pump room after a valve was errantly thrown. Before proceeding the entire rig crew met for a safety meeting. 10/31/2007: Began pumping the first stage cement job and completed in order. (Waiting on the cement) Began to mix "mud push" and mix water for second stage cement job. Pump the second stage cement job and wait on cement to cure. 11/01/2007: Begin to nipple down the diverter line and nipple up BOP equipment. 11/02/2007: Finish nippling up the BOPE and tested the BOPE to 250 / 4000 psi. Rigged down the testing equipment and rigged up to pick up the BHA. 11/03/2007: Finish picking up the BHA and ran in the hole to 455'. Drilled out the ECP stage tool and • washed down to the top of the cement at 836'. Tested the casing to 1500 psi and drilled out the cement, float equipment, shoe and twenty feet of new formation. Performed a F.I.T. to 12.8 ppg and drilled ahead. 11/04/2007: Drilled and slide to 1420' and circulated bottoms up. Drilled 15 more feet (1435') so we are past the last coal bed. Circulate hole clean at 9 5/8" casing point. Pumped a 30 bbl walnut sweep at 25 ppb to gauge the hole, followed by a 30 bbls and a 30 ppb LCM pill. Circulated the hole clean past bottoms up and pulled out of the hole and laid down the smart tools and the 8" drill collars. Rigged up the casing equipment and began running the 9 5/8" casing. 11/05/2007: Pickup and run 9 5/8 inch casing. Per running order check float and run in to 872 ft. Circulate and condition mud above shoe at 5 barrels per minute at 105 psi. Up weight, and continue to run in hole with casing to 1428 ft. Pickup three feet and rig -up head pin and circulate. Continue to run casing and rig up cement head and manifold. Test line to 4000 psi. Circulate and condition mud. Break circulation and wait for Schlumberger to mix cement. Start primary first stage of cementing job, than start pumping plug. With first stage of cement job done check float, and set packer with 600 psi and open ports with 670 psi. Start second stage of cement job. Circulate with cement pumps to ports to clean up annular from cement job. Use 50 strokes per minute at 150 psi and 130 bbl. Continue to push 60 bbl of mud at 50 strokes per minute (spm) and 100 psi. Drop plug and pump plug and hold pressure at 1200 psi for ten minutes. Lay down two joints and blow down lines. Rig down and cement and casing equipment. Begin nippling up to change out BOP's and rams. Change from 9 5/8 inch to 5 inch. Make up a test joint and begin testing BOP's at 250 — 400 psi. Pull out of hole and make up a wear ring, annular valve plug. Clean out system, set wear ring, and Test. Lay down pup, and makeup pipe single. Stand back pipe in rack. 11/06/2007: Circulate and build mud. Perform rig service. Prepare to pickup bottom hole assembly. Pick up bottom hole assembly and trip in hole. Tag ECP and rotary drill ECP stage tool, and cement from 849 ft. to 869 ft. at 15 WOB, 70 RPM. Trip in hole to 1325 ft. and tag up to cement. Circulate and condition mud at 9 barrels per minute (bpm). Test casing at 2500 psi for 30 minutes. Record results on chart. Held safety meeting and held choke drill. Start drilling from 1325 ft. to 1384 ft. at 100 RPM and 4 -5 Ell EPOCH 18 Chevron CHEVRON M -17 Torque, 10 -15 WOB. Continue to rotary drill out shoe track, and twenty feet more of new hole to 1455 ft. Circulate and condition mud, continue to build volume. Perform FIT test and clean shakers. We Held a successful FIT test. Commenced pulling out of hole, and rigged up ABPA to mud manifold. Makeup sensor on stand pipe.; Baker MWD hands assembling tools on rig floor, than installed auto driller. The crane is moving mud chemicals to hopper. Mud pits are being cleaned. 11/07/2007: Performing tasks to clean rig. Cleaning pipe racks. Waiting on Baker to test tools. Continuing to build volume and clean out shaker pits. Picking up Baker MWD tools. Circulate and condition mud. Changing out mud system. Displace well with new mud. 9.1 PPG at 44 viscosities. Condition test stand pipe. Tag bottom at 1455 ft. Circulate and wait for MWD to decode tools. Commence drilling from 1455 ft. to 1500 ft., at 100 RPM, 1250 psi, 8 -12 WOB, and 125 ROP. Drilling in stages to 2177 ft. Working through tight and sticky places in hole. Problems at connection. Pump not working. Drilling at 230 -270 torque on bottom. Add and mix chemicals all night long with water 10 to 20 bbls per hour. 11/08/2007: Rotary drilling to 2550 ft., at 120 RPM 3 -4 torque, 5 -10 WOB, pump pressure at 1800 psi, and 130 ROP. Experienced down time due to disconnected air line form IBOP. Raise pump pressure and continue to drill. Switched to number two pump at 105 strokes per minute (spm). Drill to 2833 ft. Continue to drill to 3200 ft. same perimeters as before except RPM 120 -130, WOB 8 -15K . Continue to drill to 3572 ft. Pull out of hole and log last 70 ft drilled with LWD tool. At test point one. Tripping out of hole to shoe. Lost 3605 bbls of mud a total of 439 bbls. 11/09/2007: Tripping out of hole to 2557 ft. Perform rig service on top drive. Tripping back in hole to 3500 ft. Wash and ream to 3572 ft. Continue to drill to 3873 ft. Using 120 RPM, torque 6.0, and pump pressure at 1850 psi. Logging open hole at 3677',3817', and 3844 ft. Once finished with logging tests drill to 4122 ft., ROP 115 -145 ft/hr., WOB 6 -10. From 4112 ft slowed to 20 -30 ft. per hour. Continued to drill in stages to 4620 ft. Logging open hole at 4204,4351, and at 4551 ft. • 11/10/2007: Log test open hole at 4586 ft. Continue to drill to 4995 ft. RPM still 120, and torque at 10- 13, flow is 12.5 bbls at 2000psi. Logging open hole and test formation at 5120 ft. Continuing to drill to 5186 ft. Continuing to drill to 5285 ft Logging open hole at 5259 ft. Perform rig service. Continuing to drill to 54696 ft. Shut down top drive due to ram leaking. Drilling to 5601 ft. Fluid loss 178 bbls. 11/11/2007: Continuing to drill from 5601 ft. to 5710 ft Circulate and condition mud. Pump thirty barrels of walnut sweep to clean hole. Tripping out of hole and monitor well. Hit tight spot and held 4600 ft. and 30k over and could not work pipe through. Pump out of hole from 4600 ft. to 2800 ft. Pull out of hole without pumping to 1420 ft. Continue to circulate and condition mud. Monitor static mud loss rate of 3 bbls per hour. Pump 30 bbl walnut sweep around at 98 bpm and 900 psi. Continue to circulate and condition mud. Still monitoring well. Tripping out of hole to lay down BHA. Using crane to lay down flex collars. Lay down HACL auto track and LWD tools. Pick up BHA and HaCI for wiper trip. Trip in hole to shoe. Perform rig service of drill floor and top drive. Wash and ream through tight spot. 11/12/2007: Tripped in to hole to 2992 ft. Wash and reamed tight spots at 3315, 3354, 3423, 3674, 3689, 3778, 3804, 3874, 4164, 4885, 5145, and 5375 ft Wash and reamed last three stands to bottom at 5710 ft. Circulate and condition mud. Pump thirty bbls of walnut plug to sweep the hole. Trip out of hole to work tight spots t 5430, 5105, 5058, 4782, 4490, 4435, and 4270 ft. Pumped through tight spot at 3980 ft. Pulled good through tight spot. Monitor well at shoe. Found two barrels loss per hour. Laid down BHA, and racked back heavy weight drill pipe. Tripped out of hole and cleaned drill floor and laid down tools. Test BOP's and pulled wear bushing ring. Rigged up drained stack. Make up test joint and run test plug. Wash stack out using stands of five inch drill pipe. Commence to nipple down old rams to nipple up for the new rams for the thinner drill pipe. Change rams to 7 inch. Test rams from 250 — 4000 psi. Prepare to rig up to run casing. Rig up casing tools. 10 11/13/2007: Run 7 inch casing. Run in hole to 3350 ft. Circulate bottoms up. Continue to run in casing to 5638 ft. Make up hanger and break circulation. Makeup landing stands. Continue to wash down pipe [I EPOCH 19 Chevron IMO CHEVRON M -17 at 40 (spm) at 325 psi. Work until hole clean. Pump and circulate to condition hole. Makeup cement head and load dart. Circulate and condition mud at 45 (spm), and 325 psi. Hold pre safety job meeting. Load cement iron on rig floor. Rig up cement lines and manifold. Pump five barrels of water. Drop dart and commence cement job. Run casing cement pressure test for thirty minutes at 3500 psi. Monitor well. Rig down cement lines and cement head. 11/14/2007: Rigged tools to run casing. Ran casing out length of joint from hanger and laid down double sub. Performed miscellaneous cleaning on rig floor,. Flushed out stack. Packed off and ran LDS and tested for thirty minutes per VETCO Gray. Laid down landing joint. Began tripping and laid down drill pipe of 96 drill collars. Slip and cut 102 ft of drill line. Nipple up and down the BOP's to change rams. Changed out top rams from 5" to 3.5" Performed rig service on top drive, and changed out rams on top drive. Changed out gear oil on top drive. Removed 4.5 saver sub. Replaced BOP actuator stem. Performed another rig service and inspected top drive, and draw works. Continued with various jobs to clean and service rig. Installed 4.5" saver sub with 4.5 dies and head guide. Test BOP's by making up 5" test joint. Installed test plug and pressured up. Test plug leaked. The annular leaked. Installed new rubber. Work annular several times. Reinstalled test plug and pressured up and seat test BOP's. Test from 250 to 3000 p si. Tested 5" flair valve, dart valve, and FUR valve. Tested upper and lower BOP's form 250 to 4000 psi. Held safety meeting. Held abandon platform drills. Retested Low rams and annular. Retested due to poor line quality. Laid down test tool. And rigged down test joint. Tested BOP's as kill line and lower blind rams, and HCR valves 1,2,3,12, and 13. Picked up tools to makeup 3.45" test joint. 11/15/2007: Test 3.5" pipe rams, hydril, 3.5" choke manifold valves 7,8,9, 13, choke HCR and manual choke 3.5 TIW and dart valves. Laid down test tool and rigged down test equipment. Pulled test plug, and set wear bushing. Move back and test stand. Change out saver sub from 4.5" to 3.5 ". Prep rig floor to pick up Bottom Hole assembly. Began tripping into hole picking up bottom hole assembly and down load MWD. Load nuclear source. Pick up heavy weight drill pipe and jars. Circulate and condition hole mud. Pulse test MWD tool with 7.5 barrels per minute to 1500 psi. Commence tripping in hole to 1867 ft. • While circulating to bring mud weight up. Continue to trip in hole while making -up bottom hole assembly. Continue to circulate and condition mud. Fill pipe at 27 strokes per minute of 565 psi. Rotate and recirculate up to 160 thousand. Down rotate 115 thousand to 130 thousand at 70 rpm and 6 thousand torque. Rotate and drill float equipment from 5616 at the shoe and drill 20 ft. of new hole to 5730 ft. Circulate and condition mud at 69 strokes per minute at 2500 psi for FIT test. Run casing cement pressure test. Fill up drill lines. Perform test at 2000 psi. First test only good to 930psi. Second test 880 — 850 psi Third run test result were 1060 — 1040 psi, in five minutes. Equivalent circulating density of 13.5 ppg reached and bleed off test. Rigged down log test. Continue to drill from 5730 ft. 11/16/2007: Continue to drill by rotating from 5889 ft. to 6185 ft. Keeping rpm at 70, torque at six thousand, holding weight on bit constant with the pumps at 7 barrels per minute and 2500 psi. Slide from 6185 ft. to 6213 ft. continuing with 7 barrels per minute at 2500 psi. Rotate from 6213 ft .to 6475 ft. holding all previous flow, pump pressures and weight on bit. Slide for from 6475 ft. to 6505 ft. holding weight on bit, pump pressure, and .flow rate. Rotate from 6505 ft. to 6805 ft. Slide from 6805 ft. to 6823 ft. Continue to rotary drill from 6823 ft to 7670 ft., increasing perimeters for drilling. Circulate and condition mud, continuing to circulate and condition mud. • HI EPOCH 20 0 Chevron • • CHEVRON M -17 4.2. SURVEY RECORD Rectangular Rectangular Measured Inclination Azimuth TVD Vertical Coordinate Coordinate Closure Closure DLS Depth Section Azimuth +) N/S ( -) ( +) E/W ( -) (ft) (deg) (deg) (ft) (ft) (ft ) (ft ) (ft ) (deg) (deg /100ft) 0 0.00 000.00 0.00 78 0.00 000.00 78.00 0.00 0.00 0.00 0.00 000.00 0.00 128 0.18 192.74 128.00 0.08 -0.08 -0.02 0.08 192.74 0.38 178 0.09 097.38 178.00 0.15 -0.16 0.00 0.16 178.44 0.42 228 0.18 133.07 228.00 0.19 -0.22 0.10 0.24 155.12 0.24 278 0.00 000.00 278.00 0.23 -0.27 0.16 0.31 149.72 0.36 328 0.09 134.65 328.00 0.25 -0.30 0.19 0.35 148.05 0.18 378 0.18 162.33 378.00 0.34 -0.40 0.24 0.47 149.32 0.22 428 0.35 200.48 428.00 0.56 -0.62 0.21 0.65 161.40 0.47 478 0.62 197.93 478.00 0.98 -1.02 0.07 1.02 175.99 0.54 528 0.79 197.31 527.99 1.59 -1.61 -0.11 1.61 184.08 0.34 578 0.62 203.99 577.99 2.20 -2.18 -0.33 2.21 188.52 0.38 628 0.79 217.62 627.99 2.78 -2.70 -0.65 2.78 193.47 0.48 678 0.88 217.71 677.98 3.44 -3.28 -1.09 3.46 198.43 0.18 728 0.79 211.21 727.97 4.11 -3.88 -1.51 4.16 201.23 0.26 778 0.70 233.41 777.97 4.67 -4.35 -1.93 4.76 203.91 0.60 856 3.08 182.99 855.93 7.09 -6.73 -2.42 7.15 199.79 3.45 903 3.34 187.65 902.85 9.70 -9.35 -2.67 9.72 195.94 0.78 953 4.40 189.49 952.74 13.07 -12.68 -3.18 13.08 194.07 2.13 1003 6.77 190.63 1002.50 17.93 -17.47 -4.04 17.93 193.02 4.74 1053 9.85 188.88 1051.97 25.15 -24.60 -5.24 25.15 192.04 6.18 1103 13.37 184.66 1100.94 35.15 -34.59 -6.37 35.17 190.44 7.24 1153 16.72 182.11 1149.22 47.96 -47.54 -7.11 48.07 188.50 6.83 1203 20.06 179.47 1196.66 63.40 -63.31 -7.29 63.73 186.57 6.88 1253 22.35 177.10 1243.27 80.93 -81.38 -6.73 81.66 184.73 4.89 1303 23.93 174.02 1289.25 99.73 - 100.96 -5.20 101.10 182.95 3.98 1353 25.25 173.50 1334.71 119.44 - 121.64 -2.93 121.68 181.38 2.68 El EPOCH 21 • C • • I OW CHEVRON M -17 Rectangular Rectangular Measured Inclination Azimuth TVD Vertical Coordinate Coordinate Closure Closure DLS Depth Section N/S ( -) ( +) ENV ( -) Azimuth (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg) (deg /100ft) 1391 26.22 173.32 1368.94 135.05 - 138.03 -1.04 138.04 180.43 2.56 1482 26.9 174.8 1450.34 173.67 -178.5 3.17 178.53 1.04 1576 28.7 178.1 1533.49 215.82 - 222.24 5.84 222.32 2.52 1669 30.42 179.93 1614.38 260.46 - 268.11 6.61 268.19 2.09 1761 32.71 181.73 1692.77 307.64 - 316.26 5.89 316.32 2.69 1854 35.76 187.22 1769.66 359.43 - 368.36 1.71 368.36 4.66 1947 39.05 192.68 1843.55 415.82 - 423.93 -8.14 424.01 5.02 2041 42.22 195.54 1914.88 476.98 - 483.27 -23.1 483.82 3.91 2136 44.94 197.96 1983.7 542.26 - 545.95 -42 547.56 3.36 2230 48.14 198.32 2048.35 610.14 - 610.78 -63.24 614.05 3.42 2324 50.93 198.64 2109.35 681.24 -678.6 -85.91 684.02 2.97 2418 53.77 199.52 2166.76 755.15 - 748.93 - 110.25 757 3.12 2510 56.37 200.29 2219.43 829.92 - 819.84 - 135.94 831.03 2.91 2605 56.36 200.12 2272.05 908.28 - 894.07 - 163.25 908.85 0.15 2700 56.36 200.34 2324.68 986.63 - 968.28 - 190.59 986.86 0.19 2796 56.4 201.3 2377.83 1065.7 -1043 -219 1065.75 0.84 2892 56.37 201.34 2430.98 1144.68 - 1117.48 - 248.07 1144.68 0.04 2987 56.39 202.1 2483.58 1222.74 - 1190.97 - 277.35 1222.84 0.67 3081 56.36 202.43 2535.63 1299.85 - 1263.41 - 307.01 1300.17 0.3 3176 54.46 202.02 2589.56 1376.9 - 1335.8 - 336.59 1377.55 2.04 3269 52.24 201.22 2645.07 1450.54 - 1405.15 - 364.09 1451.56 2.48 3365 49.33 200.33 2705.76 1524.1 - 1474.68 - 390.49 1525.5 3.12 3459 46.56 199.83 2768.72 1593.26 - 1540.22 - 414.46 1595.01 2.97 3551 43.01 199.02 2834.01 1657.57 - 1601.32 - 436.02 1659.62 3.92 3648 39.95 197.15 2906.68 1721.48 - 1662.37 - 455.99 1723.78 3.4 3742 37.16 196.4 2980.18 1779.89 - 1718.46 - 472.91 1782.34 3.01 3836 34.38 194.38 3056.44 1834.75 - 1771.42 - 487.52 1837.28 3.21 3925 31.78 193.35 3131 1883.31 - 1818.58 - 499.18 1885.84 2.99 4019 29.95 192.58 3211.69 1931.53 - 1865.57 - 510.01 1934.03 1.99 4113 29.97 192.16 3293.12 1978.48 - 1911.42 - 520.07 1980.91 0.22 4203 29.99 190.64 3371.08 2023.44 - 1955.51 - 528.96 2025.78 0.84 E I EPOCH 22 Chevron al • • Ito CHEVRON M -17 Rectangular Rectangular Measured Inclination Azimuth TVD Vertical Coordinate Coordinate Closure Closure DLS Depth Section Azimuth ( +) N/S ( -) ( +) E/W (-) (ft ) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg) ( deg /100ft) 4298 29.95 189.25 3453.38 2070.85 - 2002.24 - 537.15 2073.05 0.73 4391 29.97 189.3 3533.96 2117.22 - 2048.08 - 544.64 2119.26 0.04 4483 30 188.5 3613.64 2163.12 - 2093.51 - 551.75 2164.99 0.43 4579 29.94 187.85 3696.81 2210.94 - 2140.97 - 558.57 2212.64 0.35 4673 29.94 188.7 3778.26 2257.74 - 2187.4 - 565.32 2259.27 0.45 4768 30.01 188.97 3860.55 2305.11 - 2234.3 - 572.62 2306.51 0.16 4863 30 188.79 3942.82 2352.53 - 2281.24 - 579.95 2353.8 0.09 4959 30 189.27 4025.96 2400.45 - 2328.65 - 587.49 2401.61 0.25 5055 29.91 189.25 4109.13 2448.32 - 2375.96 -595.2 2449.38 0.1 5147 29.78 189.04 4188.93 2494.03 - 2421.16 - 602.48 2494.99 0.18 5244 29.76 189.51 4273.13 2542.12 - 2468.69 - 610.24 2543 0.24 5336 29.84 190.1 4352.97 2587.79 - 2513.74 - 618.03 2588.6 0.33 5432 29.78 190.16 4436.27 2635.48 - 2560.72 - 626.42 2636.23 0.07 5527 29.79 190.04 4518.71 2682.64 - 2607.18 -634.7 2683.33 0.06 5624 29.31 189.81 4603.09 2730.43 - 2654.31 - 642.94 2731.07 0.51 5666 29.72 189.77 4639.64 2751.1 - 2674.7 - 646.46 2751.72 0.97 5712 30.05 189.82 4679.53 2774 - 2697.29 - 650.36 2774.58 0.71 5805 29.75 189.42 4760.15 2820.3 - 2742.99 -658.1 2820.83 0.39 5897 29.42 188.98 4840.16 2865.65 - 2787.82 - 665.37 2866.12 0.42 5989 29.26 189.86 4920.36 2910.66 - 2832.29 - 672.75 2911.09 0.5 6081 29.17 190.8 5000.66 2955.53 - 2876.46 -680.8 2955.93 0.51 6174 28.55 189.95 5082.11 3000.39 - 2920.61 - 688.89 3000.75 0.8 6266 29.71 188.82 5162.47 3045.11 - 2964.79 - 696.18 3045.43 1.4 6360 29.33 188.62 5244.27 3091.33 - 3010.57 -703.2 3091.61 0.42 6451 28.99 188.05 5323.74 3135.56 - 3054.44 - 709.63 3135.79 0.49 6546 31.02 187.12 5406 3182.89 - 3101.53 - 715.89 3183.08 2.19 6638 29.84 187.81 5485.33 3229.31 - 3147.73 - 721.94 3229.46 1.34 6729 29.25 187.19 5564.5 3274.02 - 3192.22 -727.8 3274.13 0.73 6820 30.65 186.38 5643.34 3319.24 - 3237.33 - 733.16 3319.31 1.6 6912 31.66 185.82 5722.07 3366.55 - 3284.66 - 738.21 3366.59 1.14 7010 31.36 186.43 5805.63 3417.46 - 3335.58 - 743.68 3417.48 0.45 IEl EPOCH 23 i Chevron • • I WO CHEVRON M -17 Rectangular Rectangular Measured Inclination Azimuth TVD Vertical Coordinate Coordinate Closure Closure DLS Depth Section N/S ( -) ( +) E/W ( -) Azimuth (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg) (deg /100ft) 7103 30.63 186.26 5885.35 3465.08 - 3383.17 - 748.97 3465.09 0.79 7196 30.57 186.57 5965.4 3512.16 - 3430.21 - 754.26 3512.16 0.18 7290 29.85 186.17 6046.63 3559.19 - 3477.22 - 759.51 3559.2 0.79 7384 29.24 185.23 6128.41 3605.23 - 3523.34 - 764.11 3605.24 0.81 7476 28.94 185.2 6208.81 3649.61 - 3567.88 - 768.18 3649.64 0.32 7569 28.08 185.5 6290.53 3693.67 - 3612.08 - 772.32 3693.72 0.94 7608 28.03 185.71 6324.94 3711.88 - 3630.34 - 774.11 3711.95 0.28 7670 28.03 185.71 6379.67 3740.82 - 3659.33 - 777.01 3740.91 0 [1 EPOCH 24 • Chevron 0 • CHEVRON M -17 4.3. MUD RECORD Contractor: MI Drilling Fluids Mud Types: Ge /Gelex Spud Mud 485' - 903' 6% KCI Flo-Pro NT 903' - xxxx' DATE MD MW VIS PV YP GELS FL FC SOL OIL /H20 SD MBT pH AIk CI- Ca+ 10/24/07 0 9.2 70 14 32 22/28/- 12.1 2 3.4 -/96.0 - 17.0 8.9 - 8100 80 10/25/07 0 9.2 65 13 27 21/27/- 11.2 2 3.5 -/96.0 - - 8.9 0.05 7000 80 I 10/26/07 460 9.2 60 13 20 16/25/28 12.3 2 3.5 -/96.0 - 17.0 8.2 - 7000 80 10/27/07 903 9.3 66 21 28 23/33/- 10.0 2 5.5 -/94.0 1.50 - 9.2 0.20 7000 80 10/28/07 903 9.3 50 17 15 18/27/- 11.5 2 5.5 -/94.0 1.50 - 8.2 - 7000 80 10/29/07 903 9.4 54 13 27 17/23/- 13.0 2 5.9 -/93.5 1.00 - 7.0 - 9000 80 10/30/07 903 9.4 51 16 22 14/20/- 12.0 2 5.5 -/94.0 1.00 - 7.6 - 8000 80 10/31/07 903 9.2 57 15 27 15/21/- 12.0 2 3.8 -/96.0 - - - - - - 11/1/07 903 9.2 51 11 26 15/18/- 14.0 3/- 3.5 -/96.0 - 15.0 7.5 - 7000 80 11/2/07 903 9.1+ 50 9 20 7/14/- 7.0 2/- 3.5 -/96.0 - 15.0 7.4 - 7500 40 11/3/07 903 9.3 57 21 21 7/14/- 8.0 2/- 4.7 -/95.0 - 16.0 9.5 0.10 700 240 11/4/07 1435 9.3 51 16 20 6/12/- 8.4 3/- 5.5 -/94.0 0.25 19.0 8.8 0.10 8000 80 11/5/07 1430 9.30 51 15 18 7/11/- 8.0 2/ 6.5 -/93 0.0 15.0 7.20 .40 7000 602 11/6/07 1455 9.10 43 8 17 6/8/9 8.0 2/ 2.3 -/96 0.0 0.0 9.5 040 20000 80 11/7/07 2163 9.25 42 10 18 5/7/9 5.2 2/ 2.2 -/96 0.0 1.5 8.8 0.2 20000 100 11/8/07 3571 9.2 42 11 17 7/8/- 5.4 2/ 4.3 -/94 0.0 5.0 8.5 0.20 20000 120 11/907 4601 9.25 44 12 21 9/8/- 5.2 2/ 4.3 -/94 0.0 5.0 8.7 0.3 20000 100 11/10/07 5565 9.10 43 10 18 6/9/- 5.6 2/ 3.2 -/95 0.0 4.0 8.7 0.2 21000 120 11/11/07 5710 9.1 42 11 19 7/9/- 5.6 2/ 3.6 -/95 0.0 4.0 8.7 0.4 17000 80 11/12/07 5710 9.2 47 13 18 7/10/- 4.8 2/ 3.0 -/95 0.0 4.0 8.6 0.6 24000 60 11/13/07 5710 9.2 44 11 18 6/9/- 4.8 2/ 3.0 -/95 0.0 4.0 8.8 0.5 24000 60 11/14/07 5710 9.2 46 13 18 7/10/- 5.6 2/ 3.2 -/95 0.0 4.0 8.5 0.6 21000 80 11/15/07 5770 9.25 45 12 18 7/9/- 5.6 2/ 3.3 -/95 0.0 4.0 8.3 0.6 20000 80 11/16/07 7670 9.25 42 12 16 4/7/- 5.2 2/ 3.4 -/95 0.0 4.0 8.4 0.08 19000 140 11/17/07 7670 9.2 40 12 12 4/6/- 5.6 2/ 3.4 -/95 0.0 4.0 8.2 0.6 19000 100 Ell EPOCH 25 • Chevron • • II I 11 CHEVRON M -17 4.4. BIT RECORD BIT SIZE JETS/ AVE WOB PP NO. TYPE S/N TFA IN OUT FT HRS ROP Lo —Avg — Hi RPM Lo — Avg CONDITION — Hi 1 17.5 HC 6058303 3x18 467 903 436 5.38 89.6 0.2 — 2.8 — 7.3 71 739 —1380 — 2- 2- FC- A- E- 2 /16 -WT -TD GTX-G1 1 x14cj 1534 HC 3x18 1RR 17.5 GTX-G1 6058303 1x14cj 903 903 0 n/a n/a n /a3 n/a n/a Clean out only 2 12.25 STC PG4605 3x18 903 1435 532 4.25 151.4 1.4 — 12.7 — 46 655 — 910 — 4- 5- BT- S- E- I -WT -TD XR +C 26.7 1084 3 8.5" HCC 6018847 3x16 1435 1455 20 0.46 71.7 10.0 — 15.5 — 93 723 — 738 — 1- 1- NO- A- E -I -NO -BHA MXC 1 1 x10cj 27.9 763 4 8.5" HCC 7116852 4x9 1455 5710 4255 52.00 116.2 0.9 — 15.7 — 94 890 — 1748 — 2- 3- WT- A- X- I -NO -TD HCM607Z 3x11 26.7 2125 3RR 8.5" HCC 3x16 5710 5710 0 n/a n/a n /a3 n/a n/a NG 6018847 MXC1 1x1Oc 1 Clean out run only 5 6.125 HCC 7010032 5x10 5710 7670 160 18.10 137 1.2 — 12.3 — 71 2066 — 2771 1- 3- WT- H- X- I -CT -TD HCM505ZX 40.3 — 3283 UR1 EPOCH 26 DEPTH (FT) • co -.1 O U I 7 A co N O O O O O O O O O O O O O O O O O O O O O O O_ O_ O 10///2007 A 1 0/8 /2007 I0/9 /2007 1 04 0 /2007 0 1 04 1 /2007 X/ F 1 0n 2 /2007 _r 104 3 /2007 0 10/ 4 /2007 1 04 5/2007 (/) al m 0 1 04 6 /2007 m 0) 1 0n 7 /2007 co m 104 8 /2007 fl- (/) 1 0n 9 /2007 X CO :Q (') 10 /20 /2007 C Z 1 0 /21 /2007 cn a 10 /22 /2007 y 10 /23 /2007 - w • 10 /24 /2007 - c ' ) 10 /25 /2007 • M. 10 /26 /2007 A �`�-'� I0 /27 /2007 (( `+J 10 /28 /2007 • C7 O 1 0/29/2007 • I 1040 /2007 m cn < • c o) 1 041 /2007 • O 1 1 A / 2 0 0 7 0 Z > 11 /2/2007 -I I I /3 /2007 () I I /4 /2007 ti J 11/5 /2007 11 /8 /2007 4 11/7 /2007 u) CD 1 1/8/2007 J .r- ms., 1 1 n3 /2007 n 11 n 0 /2007 i a) y 11 n 1 /2007 4 11 n 2 /2 007 • 1 1 n 3 /2007 • 11 n 4 /2007 II /15/2007 8 n 1 1 A 6 / 2 0 0 7 v 1 1 1 1 f y 1 1 7 /2007 --• T T T T 1 1 n 8 /2007 c• �° N v 11 4 9 /2 007 • w r:3 -' m -- m = 1 1/10!10 07 A r: s - co • O O== v V U) I I /2I /2 007 • r r 0 0 1 1 /22 /2007 • ("I m m r r X O M m E 1 1 /23 /2 007 • r c R1 11 /24 /2007 • m N 1 1 /2 5 /2 007 m. • l i = • v 11 /26 /2007 p . o 1 1 /27 /2 0 07 F • z 11 /28 /2007 Chevron STEELHEAD DAILY WELLSITE REPORT EPOCH • M -17 (Slot A1-9) REPORT FOR HAUCKNAUSSINE DATE Oct 28, 2007 DEPTH 903.00000 PRESENT OPERATION PREP TO RUN CASING TIME 12 AM YESTERDAY 487.00000 ' 24 HOUR FOOTAGE 416' CASING INFORMATION 27.812" @ 460 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 856' 3.08 182.99 855.93' 778' 0.70 233.41 777.97' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 17.5" HTC GTX -1 6058303 3X18, 1X14 467' 903' 436 5:38 NA CP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 227.7 @ 883.00000 15.5 @ 492.00000 89.6 92.14231 FT /HR SURFACE TORQUE 230 @ 625.00000 111 @ 772.00000 136.0 0.00000 AMPS WEIGHT ON BIT 7 @ 868.00000 .1 @ 770.00000 2.8 4.41608 KLBS ROTARY RPM 85 @ 806.00000 9 @ 517.00000 46.3 0.00000 RPM PUMP PRESSURE 1534 @ 868.00000 739 @ 488.00000 1382.8 1456.22400 PSI DRILLING MUD REPORT DEPTH 903' MW 9.3 VIS 66 PV 21 YP 28 FL 10.0 Gels 23/33/- CL- 7000 FC 2/- SOL 5.5 SD 1.50 OIL - MBL - pH 9.2 Ca+ 80 CCI MWD SUMMARY INTERVAL TO 0 TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 219 @ 874.00000 1 @ 552.00000 91.8 TRIP GAS 0 @ 467' CUTTING GAS 0 @ 903.00000 0 @ 903.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 43933 @ 874.00000 184 @ 552.00000 16915.1 CONNECTION GAS HIGH 8 ETHANE (C -2) 0 @ 903.00000 0 @ 903.00000 0.0 AVG 0 PROPANE (C -3) 0 @ 903.00000 0 @ 903.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 903.00000 0 @ 903.00000 0.0 CURRENT BACKGROUND /AVG 0 PENTANE (C -5) 0 @ 903.00000 0 @ 903.00000 0.0 HYDROCARBON INCREASED BACKGROUND GAS AT 670' SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION 670' TO 903' (TD) SAND, SANDSTONE, CONGLOMERATE SAND, BEFORE 25 MAX GRADATIONAL SAND AND COARSE SANDSTONES CONGLOMERATE, SILT AND CLAY 219 AVE 167 WITH MINOR THIN COAL AND SILT LITHOLOGY SAND, SANDSTONE, CONGLOMERATE SAND, CONGLOMERATE W/ MINOR SILT & COAL PRESENT LITHOLOGY 903' 30% SAND, 30% CONG SAND, 10% ASH, 30% SILT DAILY ACTIVITY COMMENCED LOGGING AT 485' AT 6 AM ON 10/27/07, DRILL FORMATION TO 903' WHILE TAKING GYRO SUREY EVERY 50', SUMMARY CIRCULATE HOLE AND PULL OUT OF THE HOLE TO MAKE UP CASING WASHING TOOL. EPOCH PERSONNEL ON BOARD BROWNE, SILVA DAILY COST $3160 REPORT BY LEES F. BROWNE JR. I • Chevron STEELHEAD DAILY WELLSITE REPORT EPOCH • M -17 (Slot A1-9) REPORT FOR HAUCK, VAUSSINE DATE Oct 28, 2007 DEPTH 903.00000 PRESENT OPERATION PREP TO PUMP FOR STAGE CEMENT TIME 24 HRS YESTERDAY 903.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 13 3/8" @ 893' 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 PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 903' MW 9.3 VIS 50 PV 17 YP 15 FL 11.5 Gels 18/27/- CL- 7000 FC 2/- SOL 5.5 SD 1.50 OIL - MBL - pH 8.2 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE • DITCH GAS 93 @ TG © TRIP GAS 93 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 0 PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY PULL OUT OF THE HOLE AND LAY DOWN SMART TOOLS, PICK UP WASH TOOL AND TRIP IN THE HOLE AND WASH TO BOTTOM, SUMMARY TRIP GAS 90 UNITS, PULL OUT OF THE HOLE AND LAY DOWN WASH TOOL, RIG UP TO RUN 13 3/8" CASING, RUN 13 3/8" CASING TO LANDING JOINT AND RIG UP TO CEMENT. EPOCH PERSONNEL ON BOARD BROWNE, SILVA DAILY COST $3160 REPORT BY LEES F BROWNE JR. ill 1 Chevron EPOCH STEELHEAD DAILY WELLSITE REPORT lEti • M -17 (Slot A1-9) REPORT FOR HAUCKNAUSSINE DATE Oct 29, 2007 DEPTH 903.00000 PRESENT OPERATION RUN CASING AND CEMENT TIME 24 HRS YESTERDAY 903.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 895' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 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 PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 903' MW 9.4 VIS 54 PV 13 YP 27 FL 13.0 Gels 17/23/- CL- 9000 FC 2/- SOL 5.9 SD 1.00 OIL - MBL - pH 7.00 Ca+ 80 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 LITHOLOGY PRESENT LITHOLOGY DAILY BEGAN CEMENT JOB AND PUMPED THE "MUD PUSH ". THE "MUD PUSH" WAS HALTED DUE TO THE LOSS OF FLUID IN PIT #7, MUD ACTIVITY LINES WERE TRACED AND TWO VALVES WERE REPLACED IN THE PUMP ROOM. A METAL NUT ON A ROPE WAS ADDED TO EVERY PIT AND A NEW PIT VOLUME SPREAD SHEET WAS GENERATED. WATER FLOWED INTO THE CEMENT PUMP ROOM AFTER A VALVE SUMMARY WAS ERRANTLY THROWN. BEFORE PROCEEDING THE ENTIRE RIG CREW MET FOR A SAFETY MEETING. EPOCH PERSONNEL ON BOARD BROWNE, SILVA DAILY COST $3160 REPORT BY LEES F. BROWNE JR. 1 11111 1 1 Chevron STEELHEAD DAILY WELLSITE REPORT EPOCH • M -17 (Slot A1-9) REPORT FOR HAUCKNAUSSINE DATE Oct 29, 2007 DEPTH 903.00000 PRESENT OPERATION RUN CASING AND CEMENT TIME 24 HRS YESTERDAY 903.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 895' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 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 PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 903' MW 9.4 VIS 54 PV 13 YP 27 FL 13.0 Gels 17/23/- CL- 9000 FC 2/- SOL 5.9 SD 1.00 OIL - MBL - pH 7.00 Ca+ 80 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 LITHOLOGY PRESENT LITHOLOGY DAILY BEGAN CEMENT JOB AND PUMPED THE "MUD PUSH ". THE "MUD PUSH" WAS HALTED DUE TO THE LOSS OF FLUID IN PIT #7, MUD ACTIVITY LINES WERE TRACED AND TWO VALVES WERE REPLACED IN THE PUMP ROOM. A METAL NUT ON A ROPE WAS ADDED TO EVERY SUMMARY PIT AND A NEW PIT VOLUME SPREAD SHEET WAS GENERATED. WATER FLOWED INTO THE CEMENT PUMP ROOM AFTER A VALVE WAS ERRANTLY THROWN. BEFORE PROCEEDING THE ENTIRE RIG CREW MET FOR A SAFETY MEETING. EPOCH PERSONNEL ON BOARD BROWNE, SILVA DAILY COST $3160 REPORT BY LEES F. BROWNE JR. 110 Chevron EPOCFI STEELHEAD DAILY WELLSITE REPORT • M -17 (Slot A1-9) Ell REPORT FOR SMITHNAUSSINE DATE Oct 30, 2007 DEPTH 903.00000 PRESENT OPERATION NIPPLE DOWN NIPPLE UP TIME 24 HRS YESTERDAY 903.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 895' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 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 PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 903' MW 9.4 VIS 51 PV 16 YP 22 FL 12.0 Gels 14/20/- CL- 8000 FC 2/- SOL 5.5 SD 1.00 OIL - MBL - pH 7.6 Ca+ 80 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 LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY FINISH PUMPING 1ST STAGE CEMENT JOB. WAIT ON THE CEMENT AND MIX MUD PUSH AND MIX WATER FOR 2ND STAGE SUMMARY CEMENT JOB. PUMP 2ND STAGE CEMENT JOB. WAIT ON CEMENT. EPOCH PERSONNEL ON BOARD BROWNE, SILVA DAILY COST $3160 REPORT BY LEES F. BROWNE JR. 1 I 1 III 1 Chevron STEELHEAD DAILY WELLSITE REPORT EPOCH • M -17 (Slot A1-9) REPORT FOR SMITHNAUSSINE DATE Oct 31, 2007 DEPTH 903.00000 PRESENT OPERATION NIPPLE UP BOP TIME 24 HRS YESTERDAY 903.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 895' 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 PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 903' MW 9.2 VIS 57 PV 15 YP 27 FL 12.0 Gels 15/21/- CL- - FC 2/- SOL 3.8 SD - OIL - MBL - pH - Ca+ - CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE 0 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 LITHOLOGY PRESENT LITHOLOGY CEMENT DAILY ACTIVITY SUMMARY NIPPLE DOWN DIVERTER AND NIPPLE UP BOP'S EPOCH PERSONNEL ON BOARD BROWNE, SILVA DAILY COST $3160 REPORT BY LEES F. BROWNE JR. 40 1 CHEVRON STEELHEAD DAILY WELLSITE REPORT EPOCH 0 M -17 (Slot A1-9) REPORT FOR SMITH, VAUSSINE DATE Nov 01, 2007 DEPTH 903.00000 PRESENT OPERATION NIPPLE UP BOPE TIME 24 HRS YESTERDAY 903.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 895' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 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 PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 895' MW 9.2 VIS 51 PV 11 YP 26 FL 14.0 Gels 15/18/- CL- 7000 FC 3/- SOL 3.5 SD - OIL - MBL 15.0 pH 7.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE 0 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 LITHOLOGY PRESENT LITHOLOGY CEMENT DAILY ACTIVITY SUMMARY CONTINUE TO NIPPLE UP BOPE AND PREP RIG FOR DRILLING 12.25" HOLE. EPOCH PERSONNEL ON BOARD BROWNE, SILVA DAILY COST $3160 REPORT BY LEES F. BROWNE JR. • CHEVRON EPO STEELHEAD DAILY WELLSITE REPORT 0 M -17 (Slot A1-9) Ell REPORT FOR SMITHNAUSSINE DATE Nov 02, 2007 DEPTH 903.00000 PRESENT OPERATION PREP TO P/U BHA TIME 24 HRS YESTERDAY 903.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375" @ 895' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 12.25" STC XR +c PG 4605 3X18 903 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 903' / NA MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS 0 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 LITHOLOGY PRESENT LITHOLOGY CEMENT DAILY ACTIVITY SUMMARY FINISH NIPPLING UP BOPE AND TEST BOP'S. PREPARE TO PICK UP BHA EPOCH PERSONNEL ON BOARD BROWNE, SILVA DAILY COST $3160 REPORT BY LEES F. BROWNE JR. el CHEVRON STEELHEAD DAILY WELLSITE REPORT Ell EPO • M -17 (Slot A1-9) REPORT FOR SMITHNAUSSINE DATE Nov 04, 2007 DEPTH 974.00000 PRESENT OPERATION DRILLING TIME 24 HRS YESTERDAY 903.00000 24 HOUR FOOTAGE 71' CASING INFORMATION 13.375" @ 895' 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 12.25" STC XR +c PG 4605 3X18 903' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION . 262.0 @ 970.00000 22.0 @ 904.00000 126.1 178.45636 FT /HR SURFACE TORQUE 195 @ 945.00000 91 @ 953.00000 90.3 0.00000 AMPS WEIGHT ON BIT 21 @ 970.00000 1 @ 947.00000 8.6 16.97140 KLBS ROTARY RPM 61 @ 938.00000 13 @ 945.00000 30.8 0.00000 RPM PUMP PRESSURE 1456 @ 903.00000 666 @ 919.00000 818.7 881.20178 PSI DRILLING MUD REPORT DEPTH N/A MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI 0 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 166 @ 967.00000 23 @ 951.00000 63.6 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 32920 @ 967.00000 4628 @ 951.00000 12656.3 CONNECTION GAS HIGH 0 ETHANE (C -2) 0 @ 974.00000 0 © 974.00000 0.0 AVG 0 PROPANE (C -3) 0 @ 974.00000 0 @ 974.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 974.00000 0 @ 974.00000 0.0 CURRENT BACKGROUND /AVG 75 PENTANE (C -5) 0 @ 974.00000 0 @ 974.00000 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SAND, CLAY, SILT, CARBON SHALE, COAL PRESENT LITHOLOGY 970' = 10% CARBON SHALE, 50% CLAY, 10% SAND, 30% SILT DAILY ACTIVITY PICK UP BHA, RUN IN THE HOLE AND DRILL THE ECP STAGE TOOL AT 455', DRILL SHOE AT 894' AND SUMMARY DRILL OUT TO 923' AND FIT AT 12.8 EMW, DRILLING AHEAD WATCHING FOR MUD LOSS OR GAINS. EPOCH PERSONNEL ON BOARD BROWNE, SILVA DAILY COST $3160 REPORT BY LEES F. BROWNE JR. 0 CHEVRON EPOCIE[ STEELHEAD DAILY WELLSITE REPORT Ell • M -17 (Slot A1-9) REPORT FOR SMITHNAUSSINE DATE Nov 05, 2007 DEPTH 1435.00000 PRESENT OPERATION PREP TO RUN CASING TIME 24 HRS YESTERDAY 974.00000 24 HOUR FOOTAGE 461' CASING INFORMATION 13.375" @ 895' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1435 26.22 173.32 1408.41 1391 26.22 173.32 1368.94 SURVEY DATA 1353 25.25 173.50 1334.71 1303 23.93 174.02 1289.25 1253 22.35 177.10 1243.27 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 12.25" 4 .2 STC XR +c PG 4605 3X18 903 1435 532 4:25 CP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 614.4 @ 1130.00000 21.9 @ 1229.00000 155.5 109.43247 FT /HR SURFACE TORQUE 234 @ 1039.00000 37 © 1061.00000 68.4 206.69051 AMPS WEIGHT ON BIT 48 @ 1131.00000 0 @ 1274.00000 13.5 10.68310 KLBS ROTARY RPM 58 @ 1384.00000 1 @ 1136.00000 14.6 45.00000 RPM PUMP PRESSURE 1084 @ 1369.00000 655 @ 1049.00000 926.5 1049.74402 PSI 0 DRILLING MUD REPORT DEPTH 895' MW 9.3 VIS 57 PV 21 YP 21 FL 8.0 Gels 7/14/- CL- 700 FC 2/- SOL 4.7 SD - OIL - MBL 16.0 pH 9.5 Ca+ 240 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 403 @ 1421.00000 39 @ 976.00000 140.2 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 74335 @ 1396.00000 7250 © 1227.00000 26541.0 CONNECTION GAS HIGH 0 ETHANE (C -2) 0 @ 1435.00000 0 @ 1435.00000 0.0 AVG 0 PROPANE (C -3) 0 @ 1435.00000 0 @ 1435.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 1435.00000 0 © 1435.00000 0.0 CURRENT BACKGROUND /AVG 0 PENTANE (C -5) 0 @ 1435.00000 0 @ 1435.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SAND, TUFFACEOUS CLAY, CARBONACEOUS SHALE, TUFFACEOUS SILT, COAL PRESENT LITHOLOGY 1435' = 100% TUIFFACEOUS CLAYSTONE DAILY ACTIVITY DRILL AND SLIDE FORMATION TO 1435', CIRCULATE HOLE AND CONDITION HOLE, PULL OUT OF SUMMARY THE HOLE WITH BIT #2 AND PREP TO RUN 9 5/8" CASING. ill EPOCH PERSONNEL ON BOARD BROWNE, SILVA DAILY COST $3160 REPORT BY LEES F. BROWNE JR. CHEVRON EPOCH STEELHEAD DAILY WELLSITE REPORT El • M -17 (Slot A1-9) REPORT FOR SMITH/VAUSSINE DATE Nov 05, 2007 DEPTH 1435.00000 PRESENT OPERATION PULL TRST PLUG /CLEAN PITS TIME 24 HRS YESTERDAY 1435.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8 ' @ 1435' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1435' 26.22 173.32 1408.41 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 12.25" STC XR +c PG 4605 3X18 903 1435 532 4:25 1/1 -E -I CP DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1435' MW 9.3 VIS 51 PV 16 YP 20 FL 8.4 Gels 6/12/- CL- 8000 FC 3/- SOL 5.5 SD 0.25 OIL - MBL 19.0 pH 8.8 Ca+ 80 CCI 411 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 50 @ 1435' 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 1 INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY CEMENT DAILY PICK UP AND RUN 9 5/8" CASING FILLING EVERY JOINT AND TOPPING OFF EVERY 5 JOINTS, CIRCULATED BOTTOMS UP AT 13 3/8" SHOE, GAS UNITS MAX WAS 25 UNITS, RUN CASING TO TD AND CIRCULATE OUT ACTIVITY SUMMARY 50 UNITS OF TRIP GAS, CIRCULATE HOLE AND PUMP CEMENT TO THE HOLE, RIG DOWN CASING CREW AND PREP FOR 8.5" HOLE. EPOCH PERSONNEL ON BOARD BROWNE DAILY COST $3160 III REPORT BY LEES F. BROWNE JR. CHEVRON EPOCH STEELHEAD DAILY WELLSITE REPORT HI • M -17 (Slot A1-9) REPORT FOR SMITHNAUSSINE DATE Nov 06, 2007 DEPTH 1455.00000 PRESENT OPERATION MAKE UP BHA TIME 24HRS YESTERDAY 1435.00000 24 HOUR FOOTAGE 20' CASING INFORMATION 9 5/8" @ 1430' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1455 25.25 173.50 1408.36 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 128.9 @ 1440.00000 45.9 @ 1437.00000 73.6 59.87300 FT /HR SURFACE TORQUE 281 @ 1438.00000 206 @ 1435.00000 237.4 AMPS WEIGHT ON BIT 27 @ 1438.00000 10 @ 1448.00000 15.3 13.73100 KLBS ROTARY RPM 101 © 1449.00000 45 © 1435.00000 90.5 RPM PUMP PRESSURE 1049 @ 1435.00000 723 © 1439.00000 753.4 PSI DRILLING MUD REPORT DEPTH 1430' MW 9.1 VIS 40 PV 15 YP 13 FL 9.0 Gels 5/6/- CL- 7000 FC 2/- SOL 5.5 SD - OIL - MBL 13.0 pH 8.4 Ca+ 60 CCI • MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE 1 DITCH GAS 87 @ 1435.00000 7 @ 1437.00000 27.0 TRIP GAS 12 CUTTING GAS @ © WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 16778 @ 1435.00000 1448 @ 1437.00000 5058.4 CONNECTION GAS HIGH ETHANE (C -2) 0 @ 1455.00000 0 @ 1455.00000 0.0 AVG PROPANE (C -3) 0 @ 1455.00000 0 @ 1455.00000 0.0 CURRENT BUTANE (C -4) 0 @ 1455.00000 0 @ 1455.00000 0.0 CURRENT BACKGROUND /AVG PENTANE (C -5) 0 @ 1455.00000 0 @ 1455.00000 0.0 HYDROCARBON SHOWS no shows INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUSCLAYTONE, CARBONACEOUS SHALE, COAL PRESENT LITHOLOGY 1455' = 100% TUFFACEOUS CLAYSTONE DAILY ACTIVITY FINISHED CLEANING MUD PITS FOR NEW MUD SYSTEM, MAKE UP BHA AND BIT AND RUN IN THE HOLE SUMMARY AND DRILL OUT CEMENT AND 20' OF NEW FORMATION, RUN F.I.T. AND PULL OUT OF THE HOLE AND BREAK DOWN BHA AND PREP TO MAKE UP NEW BHA WITH SMART TOOLS. EPOCH PERSONNEL ON BOARD BROWNE DAILY COST $3160 REPORT BY LEES F. BROWNE JR. • CHEVRON EPOCH STEELHEAD DAILY WELLSITE REPORT HI • M -17 (Slot A1-9) REPORT FOR LAWRENCE /BOTHNER DATE Nov 07, 2007 DEPTH 2165.00000 PRESENT OPERATION DRILLING TIME 24HRS YESTERDAY 1455.00000 24 HOUR FOOTAGE 710' CASING INFORMATION 9 5/8" @ 1430' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2041 42.22 195.54 1914.88 SURVEY DATA 1854 35.76 187.22 1769.67 1669 30.42 179.93 1614.38 1482 26.9 174.80 1450.34 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 8.5" HCC /HCM607X 7116852 4X9, 3X11 1435' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 190.9 @ 1512.00000 4.2 © 2165.00000 121.9 4.15501 FT /HR SURFACE TORQUE 325 © 2023.00000 168 @ 1623.00000 243.4 289.90259 AMPS WEIGHT ON BIT 50 © 1804.00000 0 @ 1835.00000 6.9 6.25410 KLBS ROTARY RPM 121 @ 2142.00000 27 @ 1619.00000 98.2 117.00000 RPM PUMP PRESSURE 1796 @ 2165.00000 1 @ 1710.00000 1463.3 1796.98499 PSI DRILLING MUD REPORT DEPTH 1455' • MW 9.1 VIS 43 PV 8 YP 17 FL 8.0 Gels 6/8/9 CL- 20000 FC 1/- SOL 2.3 SD - OIL - MBL - pH 9.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 529 @ 1488.00000 1 @ 2162.00000 119.1 TRIP GAS 52 @ 1455' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 102982 @ 1488.00000 867 @ 2160.00000 22979.1 CONNECTION GAS HIGH 0 ETHANE (C -2) 0 @ 2165.00000 0 @ 2165.00000 0.0 AVG 0 PROPANE (C -3) 0 @ 2165.00000 0 @ 2165.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 2165.00000 0 © 2165.00000 0.0 CURRENT BACKGROUND /AVG 78 PENTANE (C -5) 0 @ 2165.00000 0 @ 2165.00000 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SAND, TUFFACEOUS CLAYSTONE, COAL, ASH, CARBONACEOUS SHALE PRESENT LITHOLOGY 2150' = 90% TUFFACEOUS CLAYSTONE, 10% SAND DAILY ACTIVITY PREP SMART TOOLS AND DIRECTIONAL STEERING ASSEMBLY AND TRIP IN THE HOLE TO BOTTOM, SUMMARY TRIP GAS 50 UNITS, DRILL AND SLIDE FOIRMATION FROM 1455' EPOCH PERSONNEL ON BOARD BROWNE /BLEYS DAILY COST $3160 Ill REPORT BY LEES F. BROWNE JR. CHEVRON EPOCH STEELHEAD DAILY WELLSITE REPORT HI M -17 (Slot A1-9) REPORT FOR LAWRENCE /BOTHNER DATE Nov 08, 2007 DEPTH 3571.00000 PRESENT OPERATION LWD TIME 24 HRS YESTERDAY 2165.00000 24 HOUR FOOTAGE 1406' CASING INFORMATION 9 5/8" @ 1430' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3571 2806.84 3459 46.56 199.83 2768.72 SURVEY DATA 3269 52.24 201.22 2645.08 3081 56.36 202.43 2535.64 2892 56.37 201.34 2430.98 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 8.5" HCC /HCM607X 7116852 4X9, 3X11 1435' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 672.0 @ 2838.00000 4.2 © 2165.00000 122.4 15.12097 FT /HR SURFACE TORQUE 409 @ 2848.00000 240 @ 3007.00000 169.3 260.38181 AMPS WEIGHT ON BIT 37 @ 3197.00000 0 © 3245.00000 13.1 21.77640 KLBS ROTARY RPM 145 © 3524.00000 56 © 3127.00000 58.3 64.00000 RPM PUMP PRESSURE 2066 @ 3180.00000 101 @ 2929.00000 986.3 1853.75598 PSI 0 DRILLING MUD REPORT DEPTH 2159' MW 9.2+ VIS 42 PV 10 YP 18 FL 5.2 Gels 5/7/9 CL- 21000 FC 1/- SOL 2.2 SD - OIL - MBL 1.5 pH 8.8 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 501 @ 2802.00000 4 @ 2835.00000 128.0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 971933 @ 2802.00000 235 @ 3510.00000 25266.2 CONNECTION GAS HIGH 0 ETHANE (C -2) 16 @ 2569.00000 0 @ 2606.00000 0.1 AVG 0 PROPANE (C -3) 0 @ 3571.00000 0 © 3571.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 3571.00000 0 @ 3571.00000 0.0 CURRENT BACKGROUND /AVG 0 PENTANE (C -5) 0 @ 3571.00000 0 @ 3571.00000 0.0 HYDROCARBON 501 GAS KICK SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION 2797 -2807' SAND AND CLAY BEFORE 130 MAX 501 SAND WITH MODERATE TO ABUNDANT CLAY AFTER 170 MATRIX LITHOLOGY SAND, TUFFACEOUS CLAYSTONE, COAL PRESENT LITHOLOGY 3570' = 70% SAND, 30% TUFFACEOUS CLAYSTONE • DAILY ACTIVITY SUMMARY DRILL AND SLIDE FORMATION FROM 2165' TO 3571', MAKE LWD TEST EPOCH PERSONNEL ON BOARD BROWNE, BLEYS DAILY COST $3160 1 REPORT BY LEES F. BROWNE JR. • • • CHEVRON STEELHEAD DAILY WELLSITE REPORT EPOCH LOGO M -17 (Slot A1-9) 0 REPORT FOR LAWRENCE /BOTHNER DATE Nov 09, 2007 DEPTH 4622.00000 PRESENT OPERATION DRILLING TIME 24 HRS YESTERDAY 3571.00000 24 HOUR FOOTAGE 1051' CASING INFORMATION 9 5/8" @ 1430' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4622 3734' SURVEY DATA 4483 30.0 188.5 3613.65 4298 29.95 189.25 3453 4113 29.97 192.16 3293.14 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 8.5" HCC /HCM607X 7116852 4X9, 3X11 1435' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 189.8 @ 3785.00000 3.9 @ 4131.00000 115.5 105.79523 FT /HR SURFACE TORQUE 521 @ 4609.00000 260 @ 3571.00000 376.0 437.14621 AMPS WEIGHT ON BIT 47 @ 4505.00000 0 @ 4067.00000 20.6 46.86700 KLBS ROTARY RPM 146 @ 4533.00000 64 @ 3571.00000 114.6 108.00000 RPM PUMP PRESSURE 1992 @ 4622.00000 14 @ 4432.00000 1700.8 1992.02002 PSI DRILLING MUD REPORT DEPTH 3320' MW 9.3 VIS 43 PV 11 YP 20 FL 5.4 Gels 6/9/- CL- 21000 FC 1/- SOL 4.3 SD - OIL - MBL 4.0 pH 8.4 Ca+ 120 CCI MWD SUMMARY INTERVAL TO LS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 364 @ 3988.00000 1 @ 4620.00000 77.5 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 71127 @ 3988.00000 282 @ 4620.00000 14869.7 CONNECTION GAS HIGH 0 ETHANE (C -2) 0 @ 4622.00000 0 @ 4622,00000 0.0 AVG 0 PROPANE (C -3) 0 @ 4622.00000 0 @ 4622.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 4622.00000 0 @ 4622.00000 0.0 CURRENT BACKGROUND /AVG 50 PENTANE (C -5) 0 @ 4622.00000 0 @ 4622.00000 0.0 HYDROCARBON SHOWS GAS SHOW INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION 3577 TO 3593 SAND AND CLAY BEFORE 20 MAX 230 AFTER GOOD THIN CLEAN SAND BORDERED BY VERY CLAYEY SANDS. GOOD SHARP GAS KICK (BUT 55 THIN) LITHOLOGY SAND, TUFFACEOUS CLAYSTONE, COAL, VERY CARBON CLAY AND SHALE PRESENT LITHOLOGY 4600' = 50% TUFFACEOUS CLAY, 40% SAND, 10% SANDSTONE DAILY ACTIVITY SUMMARY DRILL FROM 3571 TO 4622', STOPPING TO LWD OVER SELECTED ZONES OF INTERESTS. EPOCH PERSONNEL ON BOARD BROWNE /BLEYS DAILY COST $3160 REPORT BY LEES F. BROWNE JR. • CHEVRON STEELHEAD DAILY WELLSITE REPORT EPOCH • M -17 (Slot A1-9) REPORT FOR LAWRENCE /BOTHNER DATE Nov 10, 2007 DEPTH 5710 PRESENT OPERATION CIRCULATING AND CONDITIONING MUD TIME 24:00 YESTERDAY 4622 24 HOUR FOOTAGE 1088 CASING INFORMATION 9 5/8" @ 1430' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5527 29.79 190.4 4518.73 SURVEY DATA 5624 29.31 189.81 4603.11 5666 29.72 189.77 4639.66 5710 (Projection) 29.72 189.77 4677.87 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 8.5 HCC HCM607X 7116852 4X9 3X11 5710 4275 4275 52 CSG PT DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 582.4 @ 4715 3.0 @ 5519 105.4 43.2 FT /HR SURFACE TORQUE 614 @ 5537 372 @ 4661 495.6 577.5 AMPS WEIGHT ON BIT 46 @ 4622 1 © 5670 20.2 1.8 KLBS ROTARY RPM 143 @ 5466 69 @ 5361 118.3 114.0 RPM PUMP PRESSURE 2125 @ 4991 10 @ 5478 1758.3 1912.2 PSI DRILLING MUD REPORT DEPTH 5710 / 4678 TVD MW 9.15 VIS 42 PV 10 YP 17 FL 5.6 Gels 6/9/11 CL- 19000 FC 2 SOL 3.4 SD 0 OIL 0 MBL 4.0 pH 8.8 Ca+ 100 CCI MWD SUMMARY • INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 260 @ 5612 2 @ 5582 59.5 TRIP GAS CUTTING GAS © @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 50658 @ 5254 371 @ 5582 10280.3 CONNECTION GAS HIGH ETHANE (C -2) 58 © 4812 0 @ 4937 0.9 AVG PROPANE (C -3) @ © CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 23 PENTANE (C -5) @ ©o HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE PRESENT LITHOLOGY TUFFACEOUS CLAYSTONE 100% DAILY ACTIVITY DRILLED TO T.D. AT 5710'. CIRCULATED BOTTOMS UP TWICE. CAUGHT BOTTOMS UP AFTER FIRST CIRCULATION. PUMPED SUMMARY SWEEP AROUND TO CLEAN HOLE. CONTINUE CIRCULATING. EPOCH PERSONNEL ON BOARD BLEYS / FORREST DAILY COST $3160 REPORT BY HARRY E. BLEYS 0 CHEVRON EPOCH STEELHEAD DAILY WELLSITE REPORT Ell 0 M -17 (Slot A1-9) REPORT FOR LAWRENCE / BOTHNER DATE Nov 11, 2007 DEPTH 5710 PRESENT OPERATION PULLING OUT OF HOLE TIME 24:00 YESTERDAY 5710 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 1430' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5710 (Projection) 29.72 189.77 4677.87 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 8.5 HCC HCM607X 7116852 4X9 3X11 1435 5710 4275 52.00 4- 5- WT- A- X- 1 -BT -TD CSG PT DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 5710 / 4678 TVD MW 9.15 VIS 42 PV 10 YP 17 FL 5.6 Gels 6/9/11 CL- 19000 FC 2 SOL 3.4 SD OIL MBL 4.0 pH 8.8 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS 0 GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 263 @ 4 @ N/A TRIP GAS 263 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 39 PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY CIRCULATE AND CONDITION. PULL OUT OF HOLE. RUN BACK IN WASHING TO BOTTOM. CIRCULATE BOTTOMS UP. PUMP SUMMARY SWEEP AROUND. MAXIMUM GAS 263 UNITS. PULL OUT OF HOLE. EPOCH PERSONNEL ON BOARD BLEYS / FORREST DAILY COST $3160 REPORT BY HARRY BLEYS • CHEVRON EPOCH STEELHEAD DAILY WELLSITE REPORT 0 M -17 (Slot A1-9) 1E1 REPORT FOR LAWRENCE / BOTHNER DATE Nov 12, 2007 DEPTH 5710 PRESENT OPERATION RUNNING CASING TIME 24:00 YESTERDAY 5710 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8" @ 1430' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 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 PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 5710 / 4678 TVD MW 9.15 VIS 42 PV 10 YP 17 FL 5.6 Gels 6/9/11 CL- 19000 FC 2 SOL 3.4 SD OIL MBL 4.0 pH 8.8 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE 410 DITCH GAS 430 @ 2 @ TRIP GAS 430 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 N/A PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Run in hole washing and reaming through tight spots. Wash and ream last 3 stands to bottom at 5710'. Circulate bottoms up. Record 430 units DAILY maximum gas. Pump nutplug Hi -Vis sweep around. Circulate and condition. POOH working through tight spots. Pull clean from 3890'. Monitor ACTIVITY well. Losing 2 bbls /hr. Lay down BHA. Load off tools. Pull wear ring, set test joint, wash stack with joint of DP, rig up and test BOPS. Nipple SUMMARY down /up BOPS. Change top pipe ram to 7" and test. Rig down and break down test joint and equipment. Load casing tools on floor and rig up. Run 7" casing as per Chevron. EPOCH PERSONNEL ON BOARD BLEYS DAILY COST $3160 REPORT BY HARRY BLEYS • CHEVRON STEELHEAD DAILY WELLSITE REPORT EPOCH 0 M -17 (Slot A1-9) REPORT FOR LAWRENCE / BOTHNER DATE Nov 13, 2007 DEPTH 5710 PRESENT OPERATION WAITING ON CEMENT TIME 24:00 YESTERDAY 5710 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 5700' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 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 PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 5710 / 4678 TVD MW 9.2 VIS 46 PV 13 YP 18 FL 5.6 Gels 7/10/ CL- 21000 FC 1 SOL 3.2 SD 0 OIL 0/96 MBL 4.0 pH 8.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE el DITCH GAS 18 @ 1 @ N/A TRIP GAS 18 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 N/A PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Run 7" casing to 3350. Circulate and condition. Continue running 7" casing to 5638'. Make up and run in hanger on landing stand. Add pup and DAILY wash down to 5700'. Make up cementing head and load dart. Circulate and condition while reciprocating. Record 18 units maximum gas. Rig up ACTIVITY cementing lines. Pump 5 bbls water and test. Pump 30 bbls mud push, followed by 143 bbls Litecrete cement. Drop dart. Pump 2 bbls cement SUMMARY and 5 bbls mud to release plug. Displace cement with 208 bbls mud. Bump plug to 1500psi. Check floats. Pressure test casing to 3500psi for 30 minutes. Rig down cementing head and lines. EPOCH PERSONNEL ON BOARD BLEYS DAILY COST $3160 REPORT BY HARRY BLEYS • CHEVRON �,� STEELHEAD DAILY WELLSITE REPORT • M -17 (Slot A1-9) IEI REPORT FOR LAWRENCE / RANEY DATE Nov 14, 2007 DEPTH 5710 PRESENT OPERATION Testing BOPs TIME 24:00 YESTERDAY 5710 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 5700' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 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 PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 5710 / 4678 MW 9.2 VIS 46 PV 12 YP 19 FL 5.6 Gels 7/10/ CL- 22000 FC 1 SOL 3.2 SD 0 OIL 0/95 MBL 4.0 pH 8.4 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE 0 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 N/A PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Back out landing joint from hanger. Shoe set at 5700'. Lay down double sub. Clean and organize rig floor. Flush out stack. Set pack -off. Run in DAILY LDS. Test per Vetco Gray. Lay down landing joint. Lay down drill pipe and drill collars. Slip and cut 102' of drilling line. Nipple down BOPs. ACTIVITY Change top rams from 5" to 3.5 ". Service rig and Topdrive. Change out Topdrive ram, remove 4 1/2" saver sub, replace IBOP actuator stem, and SUMMARY do gear oil change. Inspect Topdrive and drawworks. Install 4 1/2" saver sub, guide, dies and head. Make up and install 5" test joint. Rig up for testing BOPS. Begin testing all BOPE. Replace rubber in annular after observing leak. Continue testing all BOPE. EPOCH PERSONNEL ON BOARD Bleys, Silva, Hudgins DAILY COST $3985 REPORT BY Craig Silva • I CHEVRON EPOCH STEELHEAD DAILY WELLSITE REPORT • M -17 (Slot Al -9) El REPORT FOR LAWRENCE / RANEY DATE Nov 15, 2007 DEPTH 5880 PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 5710 24 HOUR FOOTAGE 170 CASING INFORMATION 7" @ 5700' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5712 30.05 189.82 4679.54 SURVEY DATA 5805 29.75 189.42 4760.16 5897 29.42 188.98 4840.17 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 4 6.125 HCC HC505ZX 7010032 5x10 5710 170 1.90 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 307.4 @ 5783 12.4 @ 5711 140.8 145.9 FT /HR SURFACE TORQUE 357 @ 5846 282 @ 5724 325.7 332.8 AMPS WEIGHT ON BIT 45 @ 5845 16 @ 5733 33.0 28.8 KLBS ROTARY RPM 88 @ 5731 66 @ 5872 73.5 69.0 RPM PUMP PRESSURE 2600 @ 5726 2066 @ 5826 2179.2 2262.9 PSI DRILLING MUD REPORT DEPTH 5730 / 4695 MW 9.2 VIS 43 PV 11 YP 16 FL 6.5 Gels 6/9/ CL- 24000 FC 1 SOL 3.0 SD 0 OIL 0/95 MBL 4.0 pH 9.5 Ca+ 120 CCI MWD SUMMARY 0 INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 920 @ 5800 0 @ 5711 288.0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 182807 @ 5800 171 @ 5711 57261.7 CONNECTION GAS HIGH ETHANE (C -2) 795 @ 5800 2 @ 5876 196.9 AVG PROPANE (C -3) 66 @ 5800 0 @ 5875 14.9 CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 50 / 440 PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SANDSTONE, SANDSTONE, SAND, COAL, TUFFACEOUS CLAYSTONE PRESENT LITHOLOGY 50% TUFFACEOUS SANDSTONE 50% TUFFACEOUS CLAYSTONE Test BOPE as per Chevron. Lay down test tool and test equipment. Pull test plug and set wear ring. Stand back test stand. Change out saver DAILY sub from 4 1/2" to 3 1/2 ". Prep rig floor. Pick up directional BHA. Upload to MWD tool. Begin running in hole. Install sources. Pick up drill pipe, ACTIVITY HWDP and jars and run in hole. Circulate and condition mud and surface test MWD tool pulse transmission. Run in hole and tag at 5500'. SUMMARY Circulate and condition. Drill out float equipment and remaining shoe tract to 5710'. Drill 20' of new hole to 5730'. Perform 2 consecutive Formation Integrity Tests (to 13.5 EMW). Bleed off and drill ahead. Drill from 5730' to 5880' at report time. EPOCH PERSONNEL ON BOARD Silva, Bleys, Hudgins, Foradas DAILY COST $3985 REPORT BY Craig Silva • CHEVRON STEELHEAD DAILY WELLSITE REPORT EPOCH C}-11 0 M -17 (Slot A1-9) REPORT FOR LAWRENCE / RANEY DATE Nov 16, 2007 DEPTH 7670 PRESENT OPERATION Circulating after reaching TD TIME 24:00 YESTERDAY 5880 24 HOUR FOOTAGE 1790 CASING INFORMATION 7" @ 5700' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5989 29.26 189.86 4920.37 6451 28.99 188.05 5323.74 SURVEY DATA 6820 30.65 186.38 5643.35 7290 29.85 186.17 6046.63 7670 (Projection) 28.03 185.71 6379.67 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 4 6.125 HCC HC505ZX 7010032 5x10 5710 7670 1960 18.10 In Hole TD of well DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 396.8 @ 7458 8.9 @ 6199 130.9 160.0 FT /HR SURFACE TORQUE 479 @ 7441 264 @ 7613 348.0 428.3 AMPS WEIGHT ON BIT 40 @ 6499 1 @ 7039 12.7 13.9 KLBS ROTARY RPM 106 @ 7348 43 @ 7441 70.2 67.0 RPM PUMP PRESSURE 3283 @ 7233 0 © 7356 2817.5 3025.1 PSI DRILLING MUD REPORT DEPTH 7323 / 6075 TVD MW 9.3 VIS 43 PV 12 YP 11 FL 5.9 Gels 4/8/ CL- 22000 FC 1 SOL 3.2 SD 0 OIL 0/95 MBL 4.0 pH 8.8 Ca+ 120 CCI 0 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 564 @ 6147 9 @ 6473 131.2 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 113380 @ 6147 1868 @ 6472 26011.6 CONNECTION GAS HIGH ETHANE (C -2) 1015 @ 7007 0 @ 6474 115.4 AVG PROPANE (C -3) 300 @ 7158 0 @ 6810 24.1 CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 50 / 65 PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY Sand, Sandstone, Tuffaceous Sandstone, Tuffaceous Claystone, Coal /Carbonaceous Shale, Volcanic Ash, Tuffaceous Siltstone PRESENT LITHOLOGY 90% Sand and Sandstone, 10% Tuffaceous Claystone DAILY ACTIVITY SUMMARY Drill from 5880' to 7670' (TD of well). Circulating to clean and condition hole before pulling out. EPOCH PERSONNEL ON BOARD Silva, Bleys, Hudgins, Foradas DAILY COST $3985 1 REPORT BY Craig Silva IIII CHEVRON STEELHEAD DAILY WELLSITE REPORT EPOCH • M -17 (Slot A1-9) REPORT FOR LAWRENCE / RANEY DATE Nov 17, 2007 DEPTH 7670 PRESENT OPERATION Running in with 5" Liner TIME 24:00 YESTERDAY 7670 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 5700' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 4 6.125 HCC HC505ZX 7010032 5x10 5710 7670 1960 18.10 1- 3- CT- H- X- 1 -CT -TD TD of well DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE © @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7670 / 6380 TVD MW 9.2 VIS 40 PV 12 YP 12 FL 5.6 Gels 4/6/ CL- 19000 FC 1 SOL 3.4 SD 0 OIL 0/95 MBL 4.0 pH 8.2 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS 0 GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 287 @ pumping sweep at TD 2 @ breaking circ N/A 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 N/A PENTANE (C -5) @ © HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Circulate, clean and condition hole. Pump around 40 bbl nut plug and Hi -Vis sweeps. Observe moderate amounts of fine coal, large coal fragments and fine sand back on first sweep with 287 units maximum gas. Observe only very spotty fine coal and sand on second sweep, with 33 DAILY units maximum gas. Continue to circulate and condition hole. Hole clean and no problems. Fill trip tank. Monitor well. Pump dry job. Pull out of ACTIVITY hole. Lay down unused third party tools. Rig down AUTOTRAK. Pull to BHA. Monitor well. Stand back HWDP and jars. Lay down all directional SUMMARY and logging tools. Remove neutron sources. Download recorded data from LWD /MWD collar. Rig down decoder and transducers. Move 3 1/2" HWDP to off driller side pipe rack. Prepare to run 5" casing. Pick up and make up cementing head. Rig up casing running tools. Hold pre -job meeting on safety and procedures for running 5" liner. Run 5" liner as per Chevron. EPOCH PERSONNEL ON BOARD Silva, Bleys, Hudgins, Foradas DAILY COST $3985 REPORT BY Craig Silva III CHEVRON EPOCH STEELHEAD DAILY WELLSITE REPORT � ii 3 • M -17 (Slot A1-9) REPORT FOR LAWRENCE / RANEY DATE Nov 18, 2007 DEPTH 7670 PRESENT OPERATION Pulling out of hole with 5" liner TIME 24:00 YESTERDAY 7670 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 5700' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 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 PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7670 / 6380 TVD MW 9.2 VIS 43 PV 12 YP 13 FL 5.3 Gels 4/7/ CL- 25000 FC 1 SOL 2.9 SD 0 OIL 0/95 MBL 4.0 pH 8.2 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE ill DITCH GAS 1025 @ 5770 (RIH) 1 @ TRIP GAS 1025 (Max @5770) CUTTING GAS @ @ WIPER GAS 120 (Max before 5770) CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG Bkgrnd of 8 when circ PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Run in hole with 52 joints of 5" Liner as per Chevron. Fill pipe every 5 joints. Pick up packer assembly, fill with fluid and let set 30 minutes. Rig down liner running tools. Make up liner setting sleeve. Rig up to run 3 1/2" pipe. Pick up pups and 1stand DP. Circulate and record weight and torque parameters. Observe maximum 22 units of gas while circulating. Set Topdrive torque to 7500. Run 3 1/2" drill pipe in hole to 5635', filling every 10 stands. Circulate bottoms up and record 120 units maximum gas. Record weight and torque parameters. Run in hole from 5636' to 5770' DAILY and take 15K weight on tight spot. Pull up with 20K over. Start pumps and observe hole packing off. Work free and pull up into shoe. Hole packing ACTIVITY off when rotating and pumping, and unable to go down with liner when pumping. String can be picked up without pumps. No extra torque when SUMMARY rotating, but packing off continues. (Due to coarse coal transport?) Work up in small increments. Circulate bottoms up (at 5 -3.5 bpm, 1050 -700 psi) and record 1025 units of trip gas. (Maximum gas for all M -17 activities to this point). Large volume of coal returns while highest gases (over 400 units) were observed. Pump out of hole from 5635'. Able to pull without problems, but unable to slack off. Periodically while pulling out, briefly circulate and condition for few minutes to check string parameters. Continue to 3886'. Observe small amount of flow. Circulate bottoms up. Record maximum 88 units of gas. Flow stopped after bottoms up. Continue to pump out of hole. Pull liner hanger to surface and inspect. Lay down hanger and rig up to handle 5" liner. Pull out of hole laying down 5" liner. EPOCH PERSONNEL ON BOARD Silva, Bleys DAILY COST $3160 1 REPORT BY Craig Silva ID
