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168-019
From To: Schwartz, Guy L (CED ; I Moo Victoria T (LtU) Cc: Juanita Lovett: Kath r ne O" onnor Subject: C34-26 PTD 168-019 update Date: Wednesday, July 15, 2020 7:46:12 AM Attachments: 10-003 M 5 C34-26 - Approved 2015-11-12.odf Guy / Victoria In 2015 we installed a K -valve in C34-26, This week we were able to successfully lockout the TRSV and puncture it to access the hydraulics. We then successfully set and tested a WLRSV which we have requested an SVS witness for. Therefore we will drop this well from our list of wells completed with alternate subsurface safety valves thanks Dan Marlowe Hilcorp Alaska, LLC Area Operations Manager - CIO Office 907-283-1329 Cell 907-398-9904 Email DMarloweCDhilcorD cpm Hilcorp A Company Built on Energy The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. while all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,282 feet N/A feet true vertical 9,931 feet N/A feet Effective Depth measured 11,024 feet See Schematic feet true vertical 9,705 feet See Schematic feet Perforation depth Measured depth 10,247 - 11,000 feet True Vertical depth 9,016 - 9,684 feet 2-3/8" 4.7 / L-80 9,868 MD 8,670 TVD Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3 / N-80 10,683 MD 9,393 TVD Packers (x5)Baker TE5 SSSV 293 MD Packers and SSSV (type, measured and true vertical depth)See schematic Weatherford LPPB Safety Valve 293 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: TVD measured true vertical Packer 7" 11,259 MD 1,732 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 23 Representative Daily Average Production or Injection Data 130269 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 168-019 50-733-20093-00-00 Plugs ADL0018756 MGS C34-26 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 319-379 194 Authorized Signature with date: Authorized Name: 253 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 27 Gas-Mcf 888 N/A Oil-Bbl 1 Water-Bbl Intermediate N/A Junk 5. Permit to Drill Number: 3 Middle Ground Shoal / MGS Oil PoolN/A measured 11,259 Size 909 Production Casing Structural Liner Length 1,732 Conductor Surface 3,830psi 10-3/4" 907 777-8387 6,340psi 1,649 9,889 Collapse Mark McKinley mmckinley@hilcorp.com Tubing Pressure 1,580psi3,130psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: Daniel E. Marlowe Operations Manager Burst PPP Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:03 pm, Jun 09, 2020 Daniel Marlowe I am approving this document 2020.06.09 14:52:10 -08'00' Daniel Marlowe DSR-6/9/2020gls 6/9/20 SFD 6/10/2020 Perforate RBDMS HEW 6/10/2020 _____________________________________________________________________________________ Updated By: JLL 06/08/20 SCHEMATIC Middle Ground Shoal Well: C-34-26 Last Completed: 05/08/2013 PTD: 168-019 API: 50-733-20093-00 PBTD =11,024’ TD =11,282’ KB: = 35’ Water Depth = 73’ MSL 7” 4 5 6 7 8 9 10 13 14 15 Tbg cut @ 9,872’ E-Line 10 3/4” 2 16 17 18 19 1a) 3 20 21 22 23 24 25 26 27 28 12 11 1b) Buttress Modified Thread w/ overshot casing patch X XN X Casing Detail Size Wt Grade Conn ID Top Btm Cement 10-3/4” 40.5 J-55 Surf 1,732’ Cmt’d w/1500 sx 7” 26# N-80 BTC Surf 211’ Cmt’d w/1200 sx 23# N-80 BTC 211’ 4,711’ 26# N-80 BTC 4,711’ 8,646’ 29# N-80 BTC 8,646’ 11,259’ Tubing Detail 2-3/8” 4.7 L-80 8rd EUE Surf 9,868’ 3-1/2” 9.3# N-80 8rd EUE 9,868’ 10,683’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 a) 293’ 293’ Weatherford LPPB Safety Valve 1 b) 293’ 293’ 2-3/8” Baker TE5 SSSV 2 2,204' 2,054' GLM #1 3 3,804' 3,422' GLM #2 4 4,845' 4,326' GLM #3 5 5,622' 5,007' GLM #4 6 6,201' 5,514' GLM #5 7 6,779' 6,023' GLM #6 8 7,357' 6,521' GLM #7 9 7,932' 7,016' GLM #8 10 8,511' 7,509' GLM #9 11 9,121' 8,029' GLM #10 12 9,692' 8,525’ 1.875" X-Nipple (1.875" ID) 13 9,700' 8,532' GLM #11 (Orifice) 14 9,735' 8,563’ 7" Baker FH Retrievable Packer 15 9,862' 8,676’ 1.791" X-Nipple (1.791" ID) 16 9,868' 8,682’ 8' 3-1/2"x2-3/8" TIW SBR Stabbed on (swallow 3 ft. stub) 17 9,880' 8,692’ Uni-Packer VII 18 10,278' 9,044’ GLM #12 (Dummy) 19 10,314' 9,076’ XO Sliding Sleeve (Shut) 20 10,331' 9,091’ Uni-Packer VII 21 10,428' 9,178’ GLM #13 (Dummy) 22 10,463' 9,210’ XO Sliding Sleeve (Shut)*SS is Upside Down (1973) 23 10,481' 9,227’ Uni-Packer VII 24 10,610' 9,345’ GLM #14 (Dummy) 25 10,644' 9,376’ XO Sliding Sleeve (Shut) 26 10,662' 9,392’ Uni-Packer VII 27 10,673' 9,401’ 2.813" 3-1/2" X-Nipple (2.813" ID) 28 10,683’ 9,410’ EOT – 3-1/2” 9.3# - N-80 - 8rd EUE Notes 12-4-76 Fish: 2’ 3-1/2” Tbg w/ “Q” Nipple @ 11,024’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status F1 9,919' 9,926' 8,727' 8,733' 7 Sqz'd F1 9,932' 9,957' 8,738' 8,761' 25 Sqz'd HK1A 10,247' 10,256' 9,016' 9,024' 9 HK1A 10,284' 10,305' 9,049' 9,068' 21 HK1B 10,355' 10,365' 9,112' 9,121' 10 HK1C 10,397' 10,417' 9,138’ 9,155’ 20’ 05/18/20 Open HK1C 10,397' 10,453' 9,150' 9,201' 56 Sqz'd HK2A 10,526' 10,540' 9,268' 9,281' 14 HK2A/HK2B 10,547' 10,644' 9,287' 9,376' 97 HK2A 10,550’ 10,570’ 9,274’ 9,292’ 20’ 05/18/20 Open HK2B 10,614’ 10,634’ 9,331’ 9,349’ 20 05/17/20 Open HK2B 10,690' 10,752' 9,416' 9,471' 62 HK3 10,786' 11,000' 9,501' 9,684' 214 10,550’ 10,570’ 9,274’9,292’ 20’ 05/18/20 HHK1CHK1C 10,39710,397'10,41710,417'9,1389,138’9,1559,155’2020’05/18/2005/18/20 OpenOpen HK2AHK2A 10,550’10,550’10,570’10,570’9,274’9,274’9,292’9,292’20’20’05/18/2005/18/20 OpenOpen HK2BHK2B 10 614’10,614’10 634’10,634’9331’9,331’,9349’9,349’2020 ////05/17/20 pOpen HK1C HK2A HK2B Rig Start Date End Date Eline 5/9/20 5/18/20 05/17/2020 - Sunday Arrive @ platform. Move platform SL tower off well. Spot ELU on pipe deck. RU riser & WLV to well. MU RS(4&2), GR-CCL & FH tool suite. Surface test CCL & FH. MU Perf Gun#1: 1.68" X 20' straight strip carrier, 4 spf, 0* phase, 8.4 gm HMX Shogun charges. PT WLV & Lub = 250/3500 - Good Test. SI well @ flowline & SI lift gas. T/IA = 69/873 CCL-to-Top Shot = 13.5' CCL-to-Bottom Shot = 33.5'. Open swab & RIH to 10700' CCL. Log up to 9666' CCL for correlation. Correct -18' & send log for correlation confirmation. Correlation correction confirmed & approved. RBIH to 10700' CCL. Log up to 10600.5' CCL to place shots on depth (10600.5 = 13.5' = 10614' Top Shot). T = 1000 psi. Fire Perf Gun#1 to perf Zone HK2B 10614' - 10634'. Log up 200' & POOH. OOH w/ all shots fired. Secure well & ELU. Turnover well to Platform Operator to bring back online producing to test separator. SDFN. Job in Progress. Fly to Platform. PJSM & permit w/ Production Operators. MIRU ELU. Re-head, MU GR/CCL tool suite w/ jar (550# over) & Perf Gun#1. Move to well. PT WLV & Lubricator= 250/3500 - Leak @ Bowen connection. Replace O-ring & re-test. Perf Gun#1: 1.68" x 20' Shogun spiral strip, 4 spf, 60* phase, 8.4 gm HMX. CCL-to-Top Shot = 14.9'. CCL-to-Bottom Shot = 34.9', T/IA/OA = 100/714/8 psi. ELU operator sets CCL depth = -10' bumped up. Open swab & RIH. Perf Gun BHA setting down @ 43' CCL. ELU operator working EL cable by hand, BHA is light. Work by hand down to 44' CCL, BHA will not move up or down. Platform Operator shuts in gas lift & bleeds IA pressure to header. BHA OAL = 38.15'. Tbg hngr to zero point (-10' bump up CCL depth) = 17', top of rope socket @ tbg hngr. Tbg = 50. No change, still detained. Close WLV. Bleed off all pressure above WLV. Lift lubricator off WLV, no overpull on lub while picking up, & clamp EL cable @ top of WLV. Strip down 50' of EL cable & inspect for defective cable. Cable all good. Check turns on swab & master valve, no tools across either. RU platform pump to ELine pump-in sub. Pump FIW to tbg. No change, still detained. Shut down pump. Secure well & ELU. SDFN. Job in Progress. 05/09/2020 - Saturday 05/10/2020 - Sunday PJSM & permit. T/IA = 10/70/8. Open WLV, still detained. PU to 580#, work EL cable by hand up to 780#. Pump 12 bbl diesel to tbg while working wire. Work up to 1000# (900# overpull). Still detained. Holding in tension @ 900# overpull. Callout friction reducer from ELU shop. Friction reducer arrives platform. Blend 10 bbl friction reduced FIW pill. Pump 10 bbl pill to tbg while working wire. Slack off weight & then PUH. ~ 10th cycle BHA is moving downhole. RIH w/ perf gun BHA to 180'. PUH slowly w/ clean pickup tension. Pull past 44' clean w/ slight overpull entering lubricator. Bump up @ -10'. Stop pump. Close swab. Break off well, OOH w/ complete perf gun BHA. LD & dis-arm spiral strip gun. Rig ELU off C34-26, clean drill deck. Turn over well to Prod. Ops. to bring back online production. Job Suspended. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20093-00 168-019 Well Name MGS C34-26 Perf Gun#1 to perf Zone HK2B 10614' - 10634'. Log u Rig Start Date End Date Eline 5/9/20 5/18/20 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20093-00 168-019 Well Name MGS C34-26 05/18/2020 - Monday PJSM & permit. Surface test CCL & FH. PU Perf Gun#2: 1.68" x 20' spiral strip carrier, 4 spf, 60* phase, 8.4 gm HMX Shogun charges. Move to well, T/IA = 78/900. Shut in production @ flowline wing valve & shut in lift gas. CCL-to-Top shot = 14'. CCL-to-Bottom Shot = 34'. Open swab & RIH w/ Perf Gun#2 to 10600' CCL. Log up to 9670' CCl for correlation pass. Correct -20'. Send log for review and verification. Correction confirmed. RBIH to 10600' CCL, log up to 10536.0' CCL to place shots on depth (10536' + 14' = 10550' Top Shot). T = 990 psi. Fire perf Gun#2 to perf Zone HK2A 10550' - 10570'. Log up 200'. PUH to 9880', grease skid out of grease. Pack off line wiper. Call for grease to be flown to platform. Waiting on helicopter to arrive. EL crew begins Perf Gun#3 build. Helicopter delivers grease to platform. Load grease skid. POOH. OOH w/ all shots fired. Complete Perf Gun#3 build and PU same: 1.68" x 20' spiral strip carrier, 4 spf, 60* phase, 8.4 gm HMX Shogun charges. CCL-to Top Shot = 14' CCL-to-Bottom Shot = 34'. Move to well. Open swab, T = 1250 psi. RIH w/ Perf Gun#3 to 2174' ELM set down (2179' + 34' = 2208', GLM# @ 2204' KB). Repeated attempts to pass restriction fail. POOH. Pop off well. No obvious marks on Perf Gun#3. Work spiral strip mule shoe bend & file edges of same. Move back to well. RBIH w/ Perf Gun#3. Drift thru GLM#1 @ 2204' KB clean. TIH thru GLMs #2 -9 clean. Set down @ GLM#10, 9121' KB. PUH & RBIH w/ speed & pass w/ bobble. Fall to set down @ GLM#11, 9700' KB. Work wire w/ RIH speed, hesitation runs, PUH 300' & RBIH. 30 minutes of wire work, bobble past GLM#11. Fall to XN @ 9862' KB. 2nd PUH, bobble past same. RIH clean to 10520' CCL. 10520' CCL, log up to 10200' CCL. Correct -6.5'. RBIH to 10520' CCL. Log up to 10383' CCL to place shots on depth (10383' + 14' = 10397' CCL). Fire Perf Gun#3 to perf Zone HK1C 10397' - 10417'. Log up 200' & POOH. OOH w/ all shots fired. RD ELU. Rig riser & WLV off well, secure well & turn over to Plat. Operator. to return to production in test separator. Pack up & secure ELU kit. Fly crew to beach. Job Complete. Gun#2 to perf Zone HK2A 10550' - 10570'. Fire Perf Gun#3 to perf Zone HK1C 10397' - 10417'. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Stan W. Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Middle Ground Field, MGS Oil Pool, MGS C34-26 Permit to Drill Number: 168-019 Sundry Number: 319-379 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 vnvvv.aogcc.a loska.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, 4�/� Daniel T. Seamount, Jr. Commissioner s- / -DATED this Z- day of August, 2019. RBDMS-q6VAUG 2 3 2019 STATE OF ALASKA A ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Olt DDC 29 OOn 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑� Other Stimulate ❑ Pull Tubing ❑ 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 0 • Stratigraphic ❑ Service ❑ 168-019 - 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20093-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 44A 1MGS Will planned perforations require a spacing exception? Yes ❑ No 21 C34-26 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018756 I Middle Ground Shoal / MGS Oil 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): 11,282 9,931 11,024 9,705 3,055 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,732' 10-3/4" 1,732' 1,649' 3,130 psi 1,580 psi Intermediate Production 111,259' 17" 11,259' 11,259' 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,919 - 11,000 8,727 - 9,684 2-3/8" & 3-1/2" 4.7 / L-80 & 9.3 / N-80 10,683 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Packers (x5) see schematic & Baker fE5 SSSV, Weatherford -PPB Safety Valve See schematic & 293 (MD) 293 (TVD) 12. Attachments: Proposal Summary 0 Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑Q Service ❑ 14. Estimated Dale for 15. Well Status after proposed work: Commencing Operations: 9/15/2019 OIL E] - WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ 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: drnarlowe hilCor .Cont � �+.n al' t(v I Contact Phone: (907) 283-1329 Authorized Signature: p Date: I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: (� I 19 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: -MMS1�'AUr• 2 3 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No O Subsequent Form Required: / o — I M APPROVED BY r Approved by: COMMISSIONER 8(24(11 THE COMMISSION Date: Lq/V A���7 a �' f � 1 1 \I C.� 1 Submit Form and Fo 403 Revis tl 4/ 7 Approved application i al 11bb 12MMffttt000htN. r%I LOate of approval. - � Ads hmen s in Duplicate n Hi1.q AIa,k , LLC Well Work Prognosis Well: MGS C34-26 Well Name: MGS C34-26 API Number: 50-733-20093-00 Current Status: Producer (Gas Lift) Leg: Leg #1 Estimated Start Date: 09/15/2019 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 168-019 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Second Call Engineer: Stan Golis Office: 907-777-8356 Cell: 281-450-3071 Current Bottom Hole Pressure: 3,930 psi @ 8,727' TVD 0.45 psi/ft (8.67 ppg) at top perf Maximum Expected BHP: 3,930 psi @ 8,727' TVD 0.45 psi/ft (8.67 ppg) at top perf Max. Allowable Surface Pressure: 3,055 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary The MGS C34-26 was last worked over March 2013 as a Hemlock producer. This workover will perforate through the sliding sleeves in the lower completion into the hemlock sands. Procedure: 1. MIRU E -line, PT lubricator to 3,500 psi Hi 250 Low. 2. RU a -line guns and perforate 3. RD E -line. 4. Turn well over to production. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic Middle Ground Shoal Well: Last SCHEMATIC Completed: 05/08/2013 PTD: 168-019 Hileoro Alaaka, LLC API' 50-733-20093-00 K8:=35' Water Depth = 73! NASL PBTD=11,024' TO=11,282' Notes 12-4-76 Fish:2' 3-1/2" Tbg w/ "q' Nipple @ 11,024' Updated By: JLL 02/11/16 Casing Detail Depth (MD) Depth (TVD) SizeN26#N-80 Btm(M D) Grade Conn ID Top Btm Cement 10-3/4"J-55 293' 293' 8,733' Surf 1,732' CmVd w/1500 sx 2,054' 9,957' N-80 BTC Surf 211' HK3 7„N-80 4 4,845' BTC 211' 4,711' Cmt'd 5,622' 51007' 9,049' BTC 4,711' 8,646' w/1N-80 10,355' GUM #5 7 8TC 8,646' 11,259' GLM #6 8 7,357' 6,521' Tubing Detail GUM #7 9 7,932' 2-3/8" 4.7 L-80 8rd EUE 8,511' Surf 9,868' GLM #9 3-1/2- 9.3# N-80 8rd EUE GLM #10 9,868' 10,683' 8,525' Notes 12-4-76 Fish:2' 3-1/2" Tbg w/ "q' Nipple @ 11,024' Updated By: JLL 02/11/16 JEWELRY DETAIL Depth (MD) Depth (TVD) IDItem Btm(M D) Fallo 293' 293' Date Status Weatherford LPPB Safety Valve 9,919' 293' 293' 8,733' 2-3/8" Baker TES SSSV Sqz'd 2,204' 2,054' 9,957' GLM #1 3 3,804' 3,422' HK3 GUM #2 4 4,845' 4,326' 9 GLM#3 5 5,622' 51007' 9,049' GLM #4 6 6,201' 5,514' 10,355' GUM #5 7 6,779' 6,023' GLM #6 8 7,357' 6,521' 9,201' GUM #7 9 7,932' 7,016' 10,540' GLM #8 10 8,511' 7,509' HK2A/HK2B GLM #9 11 9,121' 8,029' 97 GLM #10 12 9,692' 8,525' 1.875" X -Nipple (1.875" ID) 13 9,700' 8,532' 10,786' 1 GLM #11 (Orifice) 14 9,735' 8,563' 7" Baker FH Retrievable Packer 15 9,862' 8,676' 1.791" -Nipple (1.791" ID) 16 9,868' 8,682' 8' 3-1/2"x2-3/8" TIW SBR Stabbed on (swallow 3 ft. stub) 17 9,880' 8,692' Uni-Packer VII 18 10,278' 9,044' GLM#12(Dummy) 19 10,314' 9,076' XO Sliding Sleeve (Shut) 20 10,331' 9,091' Uni-Packer Vll 21 10,428' 9,178'32.813" M#13(Dummy) 22 10,463' 9,210' Sliding Sleeve (Shut) `SS is Upside Down (1973) 23 10,481' 9,227'i -Packer Vll 24 10,610' 9,345'M#14(Dummy) 25 10,644' 9,376' Sliding Sleeve(Shut) 26 10,662' 9,392'i -Packer Vll 27 10,673' 9,401' /2"X-Nipple(2.813"ID) 28 10,683' 9414T-3-1/2"9.3#-N-80-8rd EUE Notes 12-4-76 Fish:2' 3-1/2" Tbg w/ "q' Nipple @ 11,024' Updated By: JLL 02/11/16 PERFORATION DETAIL Zone Top(MD) Btm(M D) Top (TVD) Btm(TVD) FT Date Status F1 9,919' 9,926' 8,727' 8,733' 7 Sqz'd F3 9,932' 9,957' 8,738' 8,761' 25 Sgid HK3 10,247' 10,256' 9,016' 9,024' 9 HK1A 10,284' 10,305' 9,049' 9,068' 21 HK1B 10,355' 10,365' 9,112' 9,121' 10 HKSC 10,397' 10,453' 9,150' 9,201' 56 5 z'd HK2A 10,526' 10,540' 9,268' 9,281' 14 HK2A/HK2B 10,547' 10,644' 9,287' 9,376' 97 HK2B 10,690' 1 10,752' 1 9,416' 9,471' 62 HK3 10,786' 1 11,000' 1 9,501' 9,684' 214 Notes 12-4-76 Fish:2' 3-1/2" Tbg w/ "q' Nipple @ 11,024' Updated By: JLL 02/11/16 H corn Alaska, LLC KB: =35' Water Depth =73'MA PBTD=11,024' TD=11,282' PROPOSED Middle Ground Shoal Well: C-34-26 Last Completed: 05/08/2013 PTD: 168-019 API: 50-733-20093-00 Notes 12-4-76 Fish: 2' 2" Tbg w/ "Cr Nipple @ 11,024' Updated By: 1LL 08/14/19 Casing Detail JEWELRY DETAIL No Depth (MD) Depth (TVD) ID Grade Conn ID Top Btm Cement Weatherford LPPB Safety Valve 1b) J-55 293' Surf 1,732' Cmt'd W/1500 sx 2,204' T N-80 BTC Surf 211' 3,422' 25 GLM #2 N-80 BTC 211' 4,711' CmYd 5 5,622' N-80 BTC 4,711' 8,646' w/1200 sx 5,514' 29# N-80 BTC 8,646' 11,259' ±10,284' GLM#6 8 7,357' Tubin Detail Future GLM #7 9 2-3/8" 4.7 L-80 8rd EUE 30 Surf 9,868' HK1C 3-1/2" 9.3# N-80 8rd EUE ±20' 9,868' 10,683' 9,692' Notes 12-4-76 Fish: 2' 2" Tbg w/ "Cr Nipple @ 11,024' Updated By: 1LL 08/14/19 PERFORATION DETAIL JEWELRY DETAIL No Depth (MD) Depth (TVD) ID Item 1 a) 293' 293' Date Weatherford LPPB Safety Valve 1b) 293' 293' 8,727' 2-3/8" Baker TE55SSV 2 2,204' 2,054' F1 GLM #1 3 3,804' 3,422' 25 GLM #2 4 4,845' 4,326' 10,256' GLM #3 5 5,622' 5,007' GLM #4 6 6,201' 5,514' 9,068' GLM #5 7 61779' 6,023' ±10,284' GLM#6 8 7,357' 6,521' Future GLM #7 9 7,932' 7,016' 9,112' GLM #8 30 8,511' 7,509' HK1C GLM #9 11 9,121' 8,029' ±20' GLM #10 12 9,692' 8,525' 1.875" X-Nipple(1.875"ID) 13 9,700' 8,532' Sgz'd GLM #11 (Orifice) 14 9,735' 8,563' 9,281' 7" Baker FH Retrievable Packer 15 9,862' 8,676' 1.791" X -Nipple (1.791" ID) 16 9,868' 8,682' 8' 3-1/2"x2-3/8" TIW SBR Stabbed on (swallow 3 ft. stub) 17 9,880' 8,692' ±9,274' Uni-Packer VII 18 10,278' 9,044' HK2B GLM#12(Dummy) 19 10,314' 9,076' ±20 XO Sliding Sleeve (Shut) 20 10,331' 9,091' 10,752' Uni-Packer VII 21 10,428' 9,178' GLM #13 (Dummy) 22 10,463' 9,210' 9,684' 1 XO Sliding Sleeve (Shut) -SS is Upside Down (1973) 23 10,481' 9,227' Uni-Packer Vll 24 10,610' 9,345' GLM #14 (Dummy) 25 10,644' 9,376' XO Sliding 5leave (Shut) 26 10,662' 9,392' Uni-Packer VII 27 10,673' 9,401' 2.813" 3-1/2" X-Nipple(2.813"ID) 28 10,683' 9,410' EOT - 3-1/2" 9.3# - N-80 - 8rd EUE Notes 12-4-76 Fish: 2' 2" Tbg w/ "Cr Nipple @ 11,024' Updated By: 1LL 08/14/19 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status F1 9,919' 9,926' 8,727' 8,733' 7 Sgid F1 9,932' 9,957' 8,738' 8,761' 25 Sgid HK1A 10,247' 10,256' 9,016' 9,024' 9 HK1A 10,284' 10,305' 9,049' 9,068' 21 HK1A ±10,284' ±10,304' ±9,037' ±9,055' ±20' Future Proposed HKiB 10,355' 10,365' 9,112' 9,121' 10 HK1C ±10,397' ±10,417' ±9,138' ±9,155' ±20' Future Proposed HK1C 10,397' 10,453' 9,150' 9,201' 56 Sgz'd HK2A 10,526' 10,540' 9,268' 9,281' 14 HK2A/HK2B 10,547' 10,644' 9,287' 9,376' 97 HK2A ±10,550' ±10,570' ±9,274' ±9,292' ±20' Future Proposed HK2B ±10,614' ±10,634' ±9,331' ±9,349' ±20 Future Proposed HK2B 10,690 10,752' 9,416' 9,471' 1 62 HK3 10,786' 11,000' 9,501' 9,684' 1 14 11 Notes 12-4-76 Fish: 2' 2" Tbg w/ "Cr Nipple @ 11,024' Updated By: 1LL 08/14/19 • • /6800e Regg, James B (DOA) From: Regg,James B (DOA) Sent: Tuesday, December 06, 2016 3:07 PM ZI (e/i c To: 'Barney Phillips' Subject: RE: SVS MGS Retest - Platform C Thank you Jim Regg Supervisor, Inspections AOGCC � `ry Z017 • MAR u 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Barney Phillips [mailto:bphillips@hilcorp.com] Sent:Tuesday, December 06, 2016 2:34 PM To: Regg,James B (DOA)<jim.regg@alaska.gov> Subject: RE: SVS MGS Retest- Platform C Hi Jim, We have 2 identical 2-3/8" Weatherford LPPB storm chokes. One is used as spare. The original valve that failed DP test on 11/19/16 (set at 60 PSI surface closing) was pulled and the 2nd valve (set at 80 PSI surface closing)was installed. We have to run the well choked back a bit on the production choke to maintain tubing pressure high enough to keep this valve open with 80 PSI closing pressure because our separator and flow line pressures are at 70 PSI and the storm choke will shut if we open the choke all of the way. On the plus side, with this higher 80 PSI closing pressure, we are able to get consistent good closures and DP tests. '--- Thanks, Barney From: Regg, James B (DOA) [mailto:jim.regg@aalaska.gov] Sent: Tuesday, December 06, 2016 9:00 AM To: Barney Phillips Subject: RE: SVS MGS Retest - Platform C Was this an in-kind replacement? Jim Regg 1 • Supervisor, Inspections •AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Barney Phillips [mailto:bphillips@hilcorp.com] Sent:Tuesday, December 06, 2016 8:14 AM To: Brooks, Phoebe L(DOA) <phoebe.brooks@alaska.gov> Cc: Regg,James B(DOA) <iim.regg@alaska.gov> Subject:SVS MGS Retest- Platform C Hello Phoebe, Please find attached a retest SVS form for well#C34-26 MGS—Platform C. This safety valve is a storm choke that failed DP test during our 180 Day SVS Cycle on 11/19/2016. The valve has since been replaced with a new valve and a higher dome charge setting and tested several times successfully yesterday. A request for inspector witness on AOGC website soon to follow this note. Thanks, earmey Ploy bphillips@hilcorp.com 907-394-2454 Mobile 907-776-7941 Platform A 907-776-7951 Platform C Hilcorp Alaska, 1,L,C 2 STATE OF ALASKA • SKA OIL AND GAS CONSERVATION CO SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool El Repair Well ❑ Re-enter Susp Well❑ Other: Install SSSV(K Valve)0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 168-019 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20093-Of FCF 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018756 MGS C34-26 FFR '1 A 2 n 1 E 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Middle Ground Shoal/E,F and G Oil Pools CC 11.Present Well Condition Summary: to,,a Total Depth measured 11,282 feet Plugs measured N/A feet true vertical 9,931 feet Junk measured 9,880 feet Effective Depth measured 11,024 feet Packer measured 9,735;9,880;10,331; feet 10,481; 10,662 true vertical9 705 feet true vertical 8,563;8,692;9,091; feet 9,227;9,392 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,732' 10-3/4" 1,732' 1,649' 3,130 psi 1,580 psi Intermediate Production 11,259' 7" 11,259' 9,910' 6,340 psi 3,830 psi Liner Perforation depth Measured depth 9,919-11,000 feet True Vertical depth 8,727-9,684 feet Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.7#/L-80 9,868'(MD) 8,682'(TVD) 7"Baker FH Ret Pkr 9,735;9,880;10,331; 8,563;8,692;9,091; Baker TE5 SSSV Packers and SSSV(type,measured and true vertical depth) Uni-Pkr VII(x4) 10,481; 10,662 (MD) 9,227;9,392 (ND) 293'(MD)293'(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: 21 534 319 816 80 Subsequent to operation: 27 854 357 905 88 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 El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ 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: 315-679 Contact Dan Marlowe(907)283-1329 Email dmarlowe©hilcorp.com Printed Name Stan W.GolisTitle Operations Manager Signature G L..11 J / Phone (907)777-8356 Date 21 16/16 / 2_ -2-4;., -/6 Form 10-404 Revised 5/2015 //, Z�/ DMS (^V FEB 1 8 2016 Submit Original Only • Middle Ground Shoal • H • Well:C-34-26 SCHEMATIC LastPTD:Completed:168019 5/8/13 Ililcorp Alaska,LLC API: 50-733-20093-00 KB:=35' Water Depth=73'MSL Casing Detail Size Wt Grade Conn ID Top Btm Cement Buttress Cmt'd y 'Nbdified 10-3/4" 40.5 J-55 Surf 1,732' w/1500 sx 1. la) '( Thread W 1b) ,, overshot 26# N-80 BTC Surf 211' 7. '' casing 23# N-80 BTC 211' 4,711' Cmt'd " Patch 7 26# N-80 BTC 4,711' 8,646' w/1200 sx 103/4" r ' x' 29# N-80 BTC 8,646' 11,259' r Tubing Detail 2-3/8" 4.7 L-80 8rd EUE _ Surf 9,868' 2 IR 7 3-1/2" 9.3# N-80 8rd EUE 9,868' 10,683' 3 1111 ' JEWELRY DETAIL Depth Depth 4 � No ID Item (MD) (ND) 1 a) 293' 293' Weatherford LPPB Safety Valve 1 b) 293' 293' 2-3/8"Baker TE5 SSSV 5 411111.I 2 2,204' 2,054' GLM#1 3 3,804' 3,422' GLM#2 6 t 4 4,845' 4,326' GLM#3 I 5 5,622' 5,007' GLM#4 7 ID 7 6 6,201' 5,514' GLM#5 1 7 6,779' 6,023' GLM#6 8 MI,; 8 7,357' 6,521' GLM#7 9 7,932' 7,016' GLM#8 9 10 8,511' 7,509' GLM#9 11 9,121' 8,029' GLM#10 10 is P 12 9,692' 8,525' 1.875" X-Nipple(1.875"ID) C 13 9,700' 8,532' GLM#11(Orifice) IM ; 14 9,735' 8,563' 7"Baker FH Retrievable Packer 1' 11 's 15 9,862' 8,676' 1.791" X-Nipple(1.791"ID) 12 16 9,868' 8 682' 8'3-1/2"x2-3/8"TIW SBR Stabbed on(swallow 3 ft. stub) 17 9,880' 8,692' Uni-Packer VII „,= 13 ig z 18 10,278' 9,044' GLM#12(Dummy) 14 ' 19 10,314' 9,076' XO Sliding Sleeve(Shut) 15 A 20 10,331' 9,091' Uni-Packer VII Tbecut i 21 10,428' 9,178' GLM#13(Dummy) @9,872 22 10,463' 9,210' XO Sliding Sleeve(Shut)*SS is Upside Down(1973) ELine } 16I r 23 10,481' 9,227' Uni-Packer VII 17 . 24 10,610' 9,345' GLM#14(Dummy) 111t +± 25 10,644' 9,376' XO Sliding Sleeve(Shut) I,: 18 -4-- 26 10,662' 9,392' Uni-Packer VII = 19 27 10,673' 9,401' 2.813" 3-1/2"X-Nipple(2.813"ID) 28 10,683' 9,410' EOT-3-1/2"9.3#-N-80-8rd EUE 20 21 r PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status t; , GR-GS 9,919' 9,926' 8,727' 8,733' 7 Sqz'd 23? GR-GS 9,932' 9,957' 8,738' 8,761' 25 Sqz'd s;, HC-HD 10,247' 10,256' 9,016' 9,024' 9 t 24 k r"' HC-HD 10,284' 10,305' 9,049' 9,068' 21 s HD-HE 10,355' 10,365' 9,112' 9,121' 10 = 25 �p11] HE-HF 10,397' 10,453' 9,150' 9,201' 56 Sqz'd 26 !MilkHI-HK 10,526' 10,540' 9,268' 9,281' 14 t`. 27 MI y HK-HN(u) 10,547' 10,644' 9,287' 9,376' 97 28 ) HK-HN(I) 10,690' 10,752' 9,416' 9,471' 62 7'., HN-HR 10,786' 11,000' 9,501' 9,684' 214 ; 4�t*,u,4t', C Notes PBTD=11,024' TD=11,282' 12-4-76 Fish:2'3-1/2"Tbg w/"Q"Nipple @ 11,024' Updated By:JLL 02/11/16 • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MGS C34-26 Wireline 50-733-20093-00 168-019 1/5/16 1/30/16 Daily Operations: 01/05/2016-Tuesday MIRU slickline and Pressure Test 1500 High/250 Low. RIH with Weatherford LPPB safety valve setting at 286'.Turn over to production and bring well on slowly to prevent shutting in well.Valve closed at"'120 PSI tubing pressure. (Charted shutin casing pressure pending). Current operating status: Casing 920 psi.Tubing 220 psi. Inj 650 mcfd. V/ Y 01/14/16-Thursday Rig up wireline and pressure test 1500 High/250 Low. Run in hole with Kobe equalizing prong to 286' WLM. Equalize SV. POOH.Run in hole with GS pulling tool to 286' WLM. Latch & pull Weatherford "LPPB"-Kobe Eq device-1.875" X- lock. POOH. Sent "LPPB" SV back to Pollard Wireline to have closing pressure reset from 120 PSI to 65 PSI closing, pressure. 01/17/16-Sunday Rig up wireline and pressure test 1500 High/250 Low. Run in hole with Weatherford "LPPB" Storm Choke (Set PSI 65) —Kobe Eq device— 1.875" X-lock to 286' WLM. Locate &set. POOH.Tubing 850 PSI/Casing 905 PSI. Bring well on to production.Tubing pressure fell to header pressure of 75 and stopped. Well is not flowing although header pressure is higher than set closing pressure of"LPPB". Made 2 more attempts of equalizing above "LPPB" and bringing well on with same results. There is a problem with dome charge setting or a mechanical issue with valve not allowing it to open. Run in hole with Kobe equalizing prong to 286' WLM. Equalize SV. POOH. Run in hole with GS pulling tool to 286' WLM. Latch & pull Weatherford "LPPB"- Kobe Eq device-1.875" X-lock. POOH.Valve sent to the beach to have inspected and rechecked for proper dome setting or mechanical issues. 01/30/16-Saturday R/U W/L. Pressure test 1500 High/250 Low. RIH w/Weatherford LPPB Storm Choke (65 PSI surface closing)—Kobe Eq Device—1.875" X-lock to 286' WLM. Locate and set in Baker TE5 TRSV. POOH. Bring well on slowly to unload well to ,1C normal state without tripping LPPB. Production choke full open. Back pressure on test separator at 65 PSI. LPPB tripped closed. Wing valve shut. Well head PSI 60. Monitor for pressure build up. Pressures recorded in SCADA. Well �1 has no build up DP. Still at 60 PSL Good test. Ran jumper line from waterflood injector C23-23 to C34-26. Injected waterflood down tubing of C34-26 to equalize &open LPPB. Very good pressure indication of LPPB opening at 850 PSI. Well is back on production. Night operator monitoring and making choke adjustments to dial in production flow& pressure in concert with LPPB settings. OF 7.4 • • e��\I%%4_s THE STATE Alaska Oil and Gas w �, ��►:'s l, of LAsKisiConservation Commission s u ,-.1,..--,4_-_--_,-.: 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pF wa Q, Main: 907.279.1433 ALA`s� Fax: 907.276.7542 ` fib www.aogcc.alaska.gov Stan Golis A) 1 1 Operations Manager 6 .) Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Middle Ground Shoal Field, E, F, & G Oil Pools, MGS C34-26 Sundry Number: 315-679 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, 216 Cathy P. Foerster Chair DATED this /Z�y of November, 2015 Encl. Ree • • RECEIVED STATE OF ALASKA NOV 0 2 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION ors !l fa/ is APPLICATION FOR SUNDRY APPROVALS A0G ...a<; 20 MG 25.280 1.Type of Request: Abandor ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Install SSSV e El 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: k... 0,,,f.„ Hilcorp Alaska, LLC s Exploratory ❑ Development D, 168-019 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service 1-_] 6.API Number: Anchorage,AK 99503 50-733-20093-00 - 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 E . MGS C34-26 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018756 Middle Ground Shoal/E,F&G Oil Pools 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): 11,282 • 9,931 • 11,024. 9,705, N/A 9,880 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,732' 10-3/4" 1,732' 1,649' 3,130 psi - 1,580 psi Intermediate Production 11,259' 7" 11,259' 9,910' 6,340 psi 3,830 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,919-11,000 - 8,727-9,684 2-3/8" 4.7#/L-80 9,868 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"Baker FH Ret. Packer, Uni-Packer VII(4)&Baker TE5 SSSV 9,735'(MD)8,563'(TVD),9,880'(MD)8,692'(TVD), 10,331'(MD)9,091'(TVD), 10,481' (MD)9,227'(TVD), 10,62'(MD)9,392'(TVD)& SSSV-293'(MD)293'(TVD). 12.Attachments: Description Summary of Proposal El 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: 11/16/2015 OIL E . WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ 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 Stan Golis Email SgOIIS@hiICOrp.COm Printed Name Stan Golis Title Operations Manager Signature 1.;,.) (10Phone (907)777-8356 Date 11/2/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 316--(40-261 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ,4 Lc)a+it-' -SSG ►' C(6 S RSOMQ+e...3„..)---g. 74: S p 2 015 V 1 ,� Spacing Exception Required? Yes ❑ No Ld Subsequent Form Required: rCy— c�L( APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: If— Z — 17.146 lispS— /110A— Submit Form and Form 10-403 Revised 5/2015 Approved application is va f r 2LGh o fhe of approval. Attachments in Duplicate Well Work Prognosis Well: C34-26 Hilcorp Alaska,Ll_c Date: 11/02/15 Well Name: Middle Ground Shoal C34-26 API Number: 50-733-20093-00 Current Status: S/I Producer(Gas Lift) Leg: Leg#1 Estimated Start Date: 11/16/15 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 168-019 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Second Call Engineer: Ted Kramer Office: 907-777-8420 Cell: 985-867-0665 Current Bottom Hole Pressure: —4,500 psi @ 9,192' TVD 0.49 psi/ft at mid perf of G-zone Maximum Expected BHP: —4,500 psi @ 9,192' TVD 0.49 psi/ft at mid perf of G-zone Max.Allowable Surface Pressure: —960 psi Maximum Gas-Lift Pressure Brief Well Summary The C 34-26 was last worked over March 2013 as a Hemlock producer. It was shut-in in September 2015 due to failure of the SCSSSV/This procedure will install a subsurface controlled subsurface safety valve in accordance with Guidance Bulletin 10-004. Suitability Evaluation: Well historic parameters Gross BPD 395 Gross Gas 325 BOPD 35 Net Gas 25 BWPD 360 Gas-Lift 300 Tubing Pressure: 80-95 psi 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^'175-200 psig.To test the valve the choke will be opened to lower the FTP which will trip the valve.To reset the valve the choke 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 and associated tubing stops at±285' 3. Pressure test tubing against closed valve to —1,000 psig and chart for 30 minutes. 4. Turn well over to production. 5. Conduct a SVS test within 2 weeks after stabilized flow. A..)e4; Z.-As,c�� � Hilcorp Alaska requests a 180 day testing frequency to align with the normal platform SVS testing schedule. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. McMurry-Macco PB Subsurface Safety valve cut sheet H . • Middle Ground Shoal Well: C-34-26 SCHEMATIC d: 5/8/13 PTD: 168 019 HiIcor,Alaska,LLC API: 50-733-20093-00 KB:=35' Water Depth=73'MSL Casing Detail Size Wt Grade Conn ID Top Btm Cement 7 Buttress 4._........Buttress 10-3/4" 40.5 J-55 Surf 1,732' Cmt'd Threaded _ w/1500 sx 26# N-80 BTC Surf 211' casing 23# N-80 BTC 211' 4,711' Cmt'd Itch 7„ 26# N-80 BTC 4,711' 8,646' w/1200 sx 103/4" 29# N-80 BTC 8,646' 11,259' A ` Tubing Detail 2-3/8" 4.7 L-80 8rd EUE Surf 9,868' 2 ii 3-1/2" 9.3# N-80 8rd EUE 9,868' 10,683' 3 i JEWELRY DETAIL Depth Depth No ID Item 4 b (MD) (ND) 1 293' 293' 2-3/8"Baker TE5 SSSV 5 B 2 2,204' 2,054' GLM#1 3 3,804' 3,422' GLM#2 4 4,845' 4,326' GLM#3 6 li 5 5,622' 5,007' GLM#4 6 6,201' 5,514' GLM#5 7 ® 7 6,779' 6,023' GLM#6 8 7,357' 6,521' GLM#7 8 6 9 7,932' 7,016' GLM#8 10 8,511' 7,509' GLM#9 9 11 9,121' 8,029' GLM#10 12 9,692' 8,525' 1.875" X-Nipple(1.875"ID) 10 B 13 9,700' 8,532' GLM#11(Orifice) - 14 9,735' 8,563' 7"Baker FH Retrievable Packer 11 6 15 9,862' 8,676' 1.791" X-Nipple(1.791"ID) 16 9,868' 8,682' 8'3-1/2"x2-3/8"TIW SBR Stabbed on(swallow 3 ft. stub) 12 X 17 9,880' 8,692' Uni-Packer VII 13 6 18 10,278' 9,044' GLM#12(Dummy) 19 10,314' 9,076' XO Sliding Sleeve(Shut) 1420 10,331' 9,091' Uni-Packer VII 15 XN 21 10,428' 9,178' GLM#13(Dummy) Tbg cut 22 10,463' 9,210' XO Sliding Sleeve(Shut)*SS is Upside Down(1973) @9,872' I 23 10,481' 9,227' Uni-Packer VII E-une 16 24 10,610' 9,345' GLM#14(Dummy) 17 f 25 10,644' 9,376' XO Sliding Sleeve(Shut) 26 10,662' 9,392' Uni-Packer VII 18 ' 27 10,673' 9,401' 2.813" 3-1/2"X-Nipple(2.813"ID) 19r00� 28 10,683' 9,410' EOT-3-1/2"9.3#-N-80-8rd EUE - 20 21 PERFORATION DETAIL -, Zone Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status 22 000 GR-GS 9,919' 9,926' 8,727' 8,733' 7 Sqz'd GR-GS 9,932' 9,957' 8,738' 8,761' 25 Sqz'd 23 Mink HC-HD 10,247' 10,256' 9,016' 9,024' 9 24 y i HC-HD 10,284' 10,305' 9,049' 9,068' 21 HD-HE 10,355' 10,365' 9,112' 9,121' 10 25 000 HE-HF 10,397' 10,453' 9,150' 9,201' 56 Sqz'd 26 mal HI-HK 10,526' 10,540' 9,268' 9,281' 14 HK-HN(u) 10,547' 10,644' 9,287' 9,376' 97 27 X HK-HN(I) 10,690' 10,752' 9,416' 9,471' 62 28 HN-HR 10,786' 11,000' 9,501' 9,684' 214 ose I Notes PBTD=11,024' TD=11,282' 12-4-76 Fish:2'3-1/2"Tbg w/"CrNipple @ 11,024' Updated By:JLL 11/02/15 . • Middle Ground Shoal - I4Well: C-34-26 PROPOSED Last Completed: 5/8/13 PTD: 168-019 Hilcorp Alaska,LLC API: 50-733-20093-00 KB:=35' Water Depth=73'MSL Casing Detail Size Wt Grade Conn ID Top Btm Cement 1 l Bum J4 Modfied 10-3/4" 40.5 J-55 Surf 1,732' Cmt'd la) 4 Tireadvd w/1500sx 1b) overshot40 26# N-80 BTC Surf 211' d 23# N-80 BTC 211' 4,711' Cmt'd p d pates 7" 26# N-80 BTC 4,711' 8,646' w/1200 sx 103/4" 29# N-80 BTC 8,646' 11,259' s II Tubing Detail 2-3/8" 4.7 L-80 8rd EUE Surf 9,868' 2 111 Z 3-1/2" 9.3# N-80 8rd EUE 9,868' 10,683' 3 in 1 JEWELRY DETAIL Depth Depth 4 l No (MD) (ND) ID Item 1 a) ±285' ±285' Subsurface controlled subsurface safety valve 1 b) 293' 293' 2-3/8"Baker TE5 SSSV 5 MAI 2 2,204' 2,054' GLM#1 3 3,804' 3,422' GLM#2 6 II i 4 4,845' 4,326' GLM#3 II5 5,622' 5,007' GLM#4 7 M i 6 6,201' 5,514' GLM#5 7 6,779' 6,023' GLM#6 8 am i 8 7,357' 6,521' GLM#7 9 7,932' 7,016' GLM#8 9 10 8,511' 7,509' GLM#9 11 9,121' 8,029' GLM#10 10 12 9,692' 8,525' 1.875" X-Nipple(1.875"ID) " 13 9,700' 8,532' GLM#11(Orifice) 14 9,735' 8,563' 7"Baker FH Retrievable Packer 4 11 is ) 15 9,862' 8,676' 1.791" X-Nipple(1.791"ID) 12 X 16 9,868' g 682' 8'3-1/2"x2-3/8"TIW SBR Stabbed on(swallow 3 ft. ;„ stub) 13 * 17 9,880' 8,692' Uni-Packer VII 18 10,278' 9,044' GLM#12(Dummy) 14 A 19 10,314' 9,076' XO Sliding Sleeve(Shut) '' 20 10,331' 9,091' Uni-Packer VII 15 MI , Tbg mit Il 21 10,428' 9,178' GLM#13(Dummy) @9,877 ,, 22 10,463' 9,210' XO Sliding Sleeve(Shut)*SS is Upside Down(1973) Eine 16 + } 23 10,481' 9,227' Uni-Packer VII 17 24 10,610' 9,345' GLM#14(Dummy) ri 25 10,644' 9,376' XO Sliding Sleeve(Shut) t" 18 ' '' 26 10,662' 9,392' Uni-Packer VII y 19 t 1 27 10,673' 9,401' 2.813" 3-1/2"X-Nipple(2.813"ID) 28 10,683' 9,410' EOT-3-1/2"9.3#-N-80-8rd EUE 20' 21 INA PERFORATION DETAIL ? It) Zone Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status �t` GR-GS 9,919' 9,926' 8,727' 8,733' 7 Sqz'd 23 V GR-GS 9,932' 9,957' 8,738' 8,761' 25 Sqz'd HC-HD 10,247' 10,256' 9,016' 9,024' 9 t 24 mit o HC-HD 10,284' 10,305' 9,049' 9,068' 21 , 25 i S HD-HE 10,355' 10,365' 9,112' 9,121' 10 iHE-HF 10,397' 10,453' 9,150' 9,201' 56 Sqz'd 26 i HI-HK 10,526' 10,540' 9,268' 9,281' 14 t, 27 Ell HK-HN(u) 10,547' 10,644' 9,287' 9,376' 97 i 28 a i! HK-HN(I) 10,690' 10,752' 9,416' 9,471' 62 1HN-HR 10,786' 11,000' 9,501' 9,684' 214 4 el V , Notes PBTD=11,024' TD=11,282' 12-4-76 Fish:2'3-1/2"Tbg w/"Q"Nipple @ 11,024' Updated By:JLL 11/02/15 • • McMiirry-Macco z ...4 . ,.>�..r a,, -.., ` 714',1- Y T r ii. n' k t '' � `Fk f14.4,'..gw� sk ,„d 1'+ „,-„,-,,,,,,,A,4,,,„„;,,,,..,,, �” ". 0'ti101, Y2=Y2 .I . ,.... t, ....c_ . . . 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. VITON ELASTOMERS • Snap-action closure. Valve disc does not throttle All elastomers are p made of Viton. in flow stream. • Suitable for gas lift wells. >' ; RUBBER VITON • Easilyfield tested.With use of a convenient test --- — — SEAT 17-4 ph stainless steel stand,the PB safety valve can be tested and „w ';r DISC �� � 17-4 ph stainless steel reset. I WIPER SEAL • No depth limitation.The PB is suitable for a wide LOCK SPRING variety of special applications. �� LOCKING BALLS J� Hold disc in open position=. LOCKING SLEEVE The PB is wireline retrievable and can be sus- ;L Holds g oSLEE E pended and packed off in any standard landing '' CLOSING SPRING nipple with the appropriate locking device. The PB , Provides closing force. can also be suspended and packed off in the tubing RECOCKING SPRING string with a collar lock mandrel. r.11 I i TRIP RING i Pushes locking sleeve The PB is available in a 50 to 3,000 psi range(PB) Up to release disc. —PRESSURE SENSING PORT and a 100 to 10,000 psi range(HP-PB). ',1,( Two fine mesh screens filter trash and sand. MAIN BELLOWS — — (3-Ply Morsel) Features i ., Retains fluid and transmits closing force to trip ring and closing spring. • Subsurface control. It .r f —BELLOWS PROTECTION UNIT • Wireline retrievability. Traps fluid in bellows to • 50 to 10,000 psi operating range. protect against overextension. • Bellows protection unit. • Positive closing pressure. ----- LOWER BELLOWS • Hard and soft disc-seat closing seal. :., (3-Ply Monel) Retains fluid and transmits dome charge closing force (il" to main bellows. I �. I i DOME Contains nitrogen charge DOME CHECK VALVE li , ... Retains nitrogen dome charge. -,1 i-I, For high pressure TAIL PLUG valve(HP-PB), + o; this is replaced with Backs u dome check valve. a� [.. 11"771 r l p heavy-duty ball o x check assembly. [DOME CAP McMurry-Macco subsurface safety valves are certified to API 14A,ASME SPPE-1 specifications and are available for class I,or 3S service. 72 a • • STATE OF ALASKA RE CEIVED ALA.OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS SEP 1 2 2013 r 1.Operations Abandon U Repair Well U •• Plug Perforations U Perforate ❑ Other r U�CC Performed: Alter Casing ISI • Pull Tubing IS • Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator XTO Energy 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development /1 Exploratory [] 168-019 • 3.Address: 9127 S Jamaica St,Englewood,CO 80112 Stratigraphic❑ Service 1 6.API Number: 50-733-20093-00. 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 0018756 Middle Ground Shoal C34-26 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): MGS E, F, G Oil Pool 11.Present Well Condition Summary: Total Depth measured 11,282 feet Plugs measured NA feet true vertical 9,908 feet Junk measured 9,880 feet Effective Depth measured 11,024 feet Packer measured 7,793 feet true vertical 9,692 feet true vertical 7,282 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1732' 10-3/4" 1732' 1642' 3130 psi 1580 psi Intermediate Production 11259' 7" 11259' 9889' 6340 psi 3830 psi Liner Perforation depth Measured depth 9919-11000 feet sa 'itE�+o aV True Vertical depth 8720-9672 feet 4�Ji Tubing(size,grade,measured and true vertical depth) 2-3/8",4.7#,L-80,EUE,8rd;EOT @ 9,868'MD 8684'TVD Packers and SSSV(type,measured and true vertical depth) 7"Baker FH Retreivable Pkr @ 8,567'MD,9735'MD;SCSSV @ 293'MD,293'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 13. Representative Daily Production Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 350 psi 500 psi Subsequent to operation: 13 12.5 570 810 psi 90 psi 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Developmenin Service L✓ Stratigraphic p Daily Report of Well Operations Yes 16.Well Status after work: Oil 0 . Gas ❑ 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 iC.O.Exempt: 312-320 Contact Sandra Haggard Email Sandra HaaaardCa�xtoenergy.com Printed Name Title Regulatory Analyst / Si 9 natur , � i Phone ��-- 1 ....,,a B �< Date 0 /_ i 0- 1 4-1 3 p. Form 10-404 Revised 10/2012 RBDMS SEP 1 2 2s ``\. it Original Only • )(To • • August 28, 2013 Alaska Oil and Gas Conservation Commission Attn:John Norman,Commissioner 333 W.7th Ave.,Suite 100 Anchorage,Alaska 99501-3539 Re: Form 10-404, report of sundry well operations Objective: Pull tubing, replace wellhead and run new gas lift string Middle Ground Shoal#C34-26 Production Well Middle Ground Shoal Field E, F&G Oil Pool Cook Inlet,Alaska API 50-733-20093-00-00 XTO Energy hereby submits the report of sundry well operations to pull the tubing, replace wellhead and run new gas lift string. Enclosed are the following attachments: 1. Form 10-404 Report of Sundry Well Operations 2. Workover Daily Activity Report 3. Current Wellbore Diagram If additional information is required, please contact me at 303-397-3672 Sincere) Sandra Haggard, Regulatory Analyst Copy to: Bola Adeyeye,Operations Engineer, Office: 303-397-3606 • • TOAAA 05-14-13 ENERGY CURRENT&PROPSOSED Completion MGS C34-26 4" ,( 4;9 ` / KB: 35' Cook Inlet,Alaska G4`3 (, Water Depth:73'MSL Leg 1,Conductor 3 O Tbg:2-3/8"4.7#L80 8rd EUE.Set:05/8/13 OF API No.:50-733-2003-00 CIA / S ud:1968 �/ 4'Pup Jt,2-3/8"4.7#L80 8rd EUE @ 289' Sp Il 4 2-3/8"Baker TE5 SSSV @ 293' 2'Pup Jt,2-3/8"4.7#L80 8rd EUE @ 294' 2-3/8"4.7#L80 8rd EUE with Side Pocket Mandrels 4'Pup Jt,2-3/8"4.7#L80 8rd EUE @ 9688' Surf Csg: 10 3/4",40.5 Ib,J55. 2-3/8"X Nipple(1.875"ID)9 Cr @ 9692' Set @ 1732'. Cmt'd w/1500 sx. 4'Pup Jt,2-3/8"4.7#L80 8rd EUE @ 9693' 1 Jt 2-3/8"4.7#L80 8rd EUE @ 9697' 6'Pup Jt 2-3/8"4.7#L80 8rd EUE @9728' Crossover 2 3/8 X 2 7/8 @9734' 7"Baker FH Retrievable Packer @ 9735' Crossover 2 3/8 x 2 7/8 @ 9742' 10'Pup jt 2-3/8"4.7#180 8rd EUE @ 9743' 6'Pup Jt 2-3/8"4.7#L80 8rd EUE @9753' 3 Jt 2-3/8"4.7#L80 8rd EUE @ 9759' 4'Pup Jt,2-3/8"4.7#L80 8rd EUE @ 9858' 2-3/8"XN Nipple(1.791"ID)9 Cr @ 9862' Longstring 7",N80 BTC.Set @ 11,259'. 4'Pup Jt,2-3/8"4.7#L80 8rd EUE @ 9864' Cmt w/1200 sx.TOC @7900' 8'3-1/2"x 2-3/8"TIW SBR Stabbed on @ 9868'(swallow 26#:Surface to 211'(Buttress Modified Thread 38 stub) 6 ft pup jt above and 4 ft pup jt below gas lift mandrels with overshot casing patch) 23#:211'to 4711'. GLM MD TVD PORT PSC PSO 26#:4711 -8646'. #1 2204 2050 12 942 1000 #2 3804 3415 12 923 963 29#:8646—11,259'. i�=, „ryJ #3 4845 4320 12 903 934 /_/J #4 5622 5000 12 885 908 /// ///� #5 6201 5509 12 863 886 12 Tbg cut @ 9872' I/ ##77 6779 6508 14 815 845 / ® #8 7932 7002 14 793 822 Uni-Packer VII 9880' ►� ��IAA 8511 7495 14 770 799 @ #10 9121 8016 14 747 775 lot #11 9700 8519 14 Orifice irdi GR-GS: 9919-26'&9932-57' (SQZ'd) J GLM#9 Dummy @ 10278' HC HD: 10,247-256'&10,284-305' fi/ XO Sliding Sleeve @ 10314'(Shut);$:401 Uni-Packer VII @ 10331' ►I Z� �J • J HD-HE: 10,355-65' GLM#10 Dummy @ 10428' 0/° dill XO Sliding Sleeve @ 10463'(Shut) e HE-HF:10,397-453' (SQZ'd) SS is Upside Down(1973) Uni-Packer VII @ 10,481' I►Z Z� 0 J � HI-HK: 10,526-540' GLM#11 Dummy @ 10610' // = HK-HN(u): 10,547-644' XO Sliding Sleeve @ 10644'(Shut)0 i Uni-Packer VII @ 10662' i. .1 3'%"X Nipple(2.813"ID)©10673' / HK-HN(I):10,690-10752' rj HN-HR: 10,786-11000' 9 ©Q FISH:2'3-W Tbg w/"Q"Nipple©11,024'(12-4-76) or 4 PBTD: 11024' #151///,"4,TD: 11282' • Daily Activity and Cost Summary_sIs L H ;Y Well Name: Middle Ground Shoal C34-26 APINWI Location Field Name Permit Number State/Province Well Configuration Type 50733200930000 TO8N-R13W-S23 Middle Ground Shoal 168-019 Alaska Directional Original KB Elevation(ft) ;Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 Jobs Category Primary Job Type/Initial Job Type Secondary Job Type/Final Job Type Start Date End Date Well Maintenance WUSL Operation 2/16/2013 00:00 2/18/2013 00:00 Objective Pre-Workover wireline prep Summary Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 1.0 2/16/2013 2/17/2013 -Rig up wireline and pressure test lubricator. -Run in hole with 2.875"gauge ring to 254'WLM tag SV.No problems.Pull out of hole. -Run in hole with 3"JDC&prong to 254'WLM.Latch and pull 3-1/2"Otis AO ball valve.Pull out of hole with safety valve. -Run in hole with 2.70"tapered drift.Tools sat down at 2142'WLM about 37'under#1 GLM.Worked tools to 2146'WLM but was very sticky.Pulled out of hole to inspect tools. -Out of hole.Tools covered in thick asphaltine/paraffin wax. -Secure equipment and SDFN. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 2.0 2/17/2013 2/18/2013 -Run in hole with 2.60"gauge ring to 2148'WLM.Hit asphaltine/paraffin:Tools sticky and could not make hole.Pull out of hole. -Consult with engineer on options involving to clean up well that will not flow.Will explore CTU or wash pipe options with rig. -Rig down wireline. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 1/1 Report Printed: 9/10/2013 Daily Activity and Cost Summary_s s f it DH il' Well Name: Middle Ground Shoal C34-26 API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200930000 TO8N-R13W-S23 Middle Ground Shoal 168-019 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(It) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 .fobs y',4., Job Category Primary Job Type/Initial Job Type Secondary Job Type/Final Job Type Start Date End Date Well Maintenance Pull Tubing 2/25/2013 00:00 3/29/2013 00:00 Objective Install new gas lift completion&RWTP Summary Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 1.0 2/25/2013 2/26/2013 00:00 Cut drilling line and prepare to move rig to new well. Start on rig maintenance,clean and service iron roughneck,remove block in choke manifold and prepare to install panic line.Prepare to move mud dock and mud products,install tool racks in cellar. Load work boat with tools that are not needed,clean off deck.Cut out drain on rig floor and tack in new drain.Install hydraulics on rig jacking system.Clean out behind rig for move,remove koomey hydraulic lines.Remove mouse hole,refit splash guard on rat hole,rig down choke line extension.Function test rig jacking system.Continue to clear landing in front of rig.Remove choke lines on side of rig.Lift hatch covers on lower mezzanine for 2900 to relocate,clean mud dock and cuttings bin location.Relocate 2900 boom rest for rig to pass. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 2.0 2/26/2013 2/27/2013 Continue with rig maintenance and moving operation.Welder cut free cat walk,removed same from beaverslide,and secure beaverslide with tugger.Clean and lubricate skid rates,start to skid rig NW to service lines.Shut in steam and prepare to blow down steam and water lines.Rig up and relocate PTS tank with 3900.Hold PJSM and execute as planned.Move DL spool,skid rig North to clear Leg#4 hatch covers.Install handrails after move.Electrician to disconnect power from rig at junction box. PTSM,Clean up landing on leg#4 and prepare to swap out hatch covers.Welder to cut out existing cable chute penetration in pump room for electrician to pull new com cables.Install cable tray to replace chute.Move jacking system to SW of rig.Electrician inspects junction box and replaced bad com cables. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 3.0 2/27/2013 2/28/2013 Continue cleaning up leg#4 deck,remove hatch cover for welder to refit and repair leaks.Set production hatch cover.Continue skidding rig between legs,repair broken hydraulic hose on jacking unit.Clean southeast deck.Start to clear upper deck to get ready to skid rig catwalk,etc.refit well head room hatch cover,untangle cables and spot in shop to ring out.Clean well head room in leg#4,install block in chock manifold for panic line. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 4.0 2/28/2013 3/1/2013 Finish installing block on choke manifold,install drilling hatch cover over C34-26 and C24-26RD. Welder to repair leak in sand trap.Skid rig NW in route to leg 1.Replace seals in rig move gripping block,assist welder to install handrails.Electrician pulling wire and toning the same.Prepare to move upper section NE to center over well.Cut out and replace cable tray under dog house.Deck crew prepare to spot PTS tank on leg#4 deck,install steam,and air service lines to rig.Install cable hangers on rig and prepare for 4"mud line installation.Replace bad communication cables from DC panel to junction box in pump room.Start filling pits with FW.Check for leaks. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 1/7 Report Printed: 9/10/2013 ltaily Activity and Cost Summary_se N E Y Well Name: Middle Ground Shoal C34-26 API/UWI Location Field Name Perrrrt Number State/Province Well Configuration Type 50733200930000 TO8N-R13W-S23 Middle Ground Shoal 168-019 Alaska Directional Original KB Elevation(ft) .Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 wr. Daily Operations ` Rpt No. Report Start Date Report End Date Operation Summary#1 5.0 3/1/2013 3/2/2013 Prepare mud lines for rrig position,set up deck for back load on work boat and prepare for mud products.Complete motor for mud mixing on#1 mud pit.Run the power to the same.Install new lighting above mud pumps,Weld to fit new choke lines to tie into SE side of the rig.Inspect fluid end and liners on MP#2.Checked and all was good.Off load 12 pallets of CaCl2 From boat,2900 overheated,boat to return in the morning.Continued cleaning and organizing rig. Installed cable tray near junction box in pump room.Continued to fit 4"mud line to rig position. Complete 20 pin cables rig out and replace bad cables.pull wires to junction box and tie into rig. Inspect MP#1 liners and fluid end. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 6.0 3/2/2013 3/3/2013 Install mud dock for pits,repair handrails on mud dock and strengthen landing.Patch holes in pit gratings,offload working boat of mud products. Finish installing mud line,skid rig on center of C34-26 well.Make up dresser sleeve on flow lone,install storm clamps,clean up cellar after move and assist welder on installing handrails.Electrician to finish DC junction box,wire new lighting in pump room, continue housekeeping and maintenance on the rig. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 7.0 3/3/2013 3/4/2013 Refit handrails in sub while cleaning and organizing.Clear back deck byDL spool,while inventory parts for mud pumps.Change 2 liners,3 swabs,and add wash plate to#3 fluid end on MP#1.Take out cement line from cellar and prepare to replace with new cement lines.Prepare 4"flow line for chock. Terminate cable in 480 panel and start#5 motor and power up rig.Test DC equipment on rig. Troubleshoot rotary table and DWB control communication cables.Install 4"flow line for choke manifold.Prepare out 6"flow line for choke.Continue housecleaning in pump room. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 8.0 3/4/2013 3/5/2013 Continue on rig maintenance list.Install 6"flow line off poor boy to pits,spool up excess DL,remove heater from board for repairs,service rig floor tuggers.Assist welder to install hand rails on top deck, cut penetration in wind wall for panic line,install valve on choke for panic line,replace cables for torque tube cradle.Continue to troubleshoot rotary table and DWB control cables,continue to organize and clean rig floor.service and inspect air slips,paint hand rails,pump through choke lines,test mud lines. Replace bad communications on Totco rig watch. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 9.0 3/5/2013 3/6/2013 Troubleshoot and repair electrical issues with draw-works B and rotary table motors.Finish building hi-pressure line for production.Build extension for hi-pressure mud line to rig.Test mud line to 3000 psi (OK).Plumb in suction strainers for Koomey air pumps.Change dies in air slips and function test. Circulate thru and test choke manifold lines(OK).Remove top of rotary table and clean under guard. Installing man-ride tugger sheave hanging brackets.Hook up jet line on flow line.Service 2900 crane boom sheaves. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 2/7 Report Printed: 9/10/2013 Daily Activity and Cost Summary_e 411&°N G I Well Name: Middle Ground Shoal C34-26 APINWI Location Field Name Permit Number State/Province Well Configuration Type 50733200930000 TO8N-R13W-S23 Middle Ground Shoal 168-019 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) ;KB-Ground Distance(ft) 'Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 10.0 3/6/2013 3/7/2013 Finish cleaning under rotary table cover,drain oil,flush and re-fill with oil.Changed out broken pillow block on rat hole.Finish installing sheave hanging brackets for man-ride tuggers.Adjust upper and lower height capacity on man-ride tuggers.Install cap on end of flow-line on leg 4.Start pressure washing rig floor.Prep to install 2900 crane stand.Clean in 3900 crane in preparation for repair work. Assist production installing injection line for C24-23. Remarks#2 Crane mechanic got here at 10:00 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 11.0 3/7/2013 3/8/2013 Repairing minor leaks in hydraulic system.Install new pressure&temp gauges for lubricating system on mud pumps.Repair light in koomey house.Replace bulbs on DC gear.Cleaning wind-wall.Assist crane mechanic with 3900 repairs.Repair hole in flowline.Set in catwalk.Pressure wash BOPS. Painting on choke manifold&windwalls.Trouble shoot beacon lights on side of derrick. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 12.0 3/8/2013 3/9/2013 Trouble shoot red navigation lights on side of derrick.Install and tag koomey lines in sub-base.Painting rig floor windwalls.Assist mechanic with 3900 crane repairs,finished and load tested(OK).Perform derrick audit.Off-load coil tubing unit from boat.Painting choke manifold. Remarks*/2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 13.0 3/9/2013 3/10/2013 Trouble shoot breaker&derrick lights.Install additional lighting above mud dock.Insulating steam lines in cellar.Spot Baker CTU and assist with CTU RU(run chicksans,install BOPs&lubricator,connect control lines).Install brake band on whip-line drum of 3900 crane.Set and weld down 2900 crane stand.Start building 10.3 ppg CaCl2 brine for killing the well after clean-out of tubing.Cleaning on rig floor&in pump room. Remarks*/2 Installed 1 brake band on 3900 whip line drum Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 14.0 3/10/2013 3/11/2013 Cont.assist Baker CTU RU.Tested Coil BOPs to 5000 psi.Test gas alarms&PVTs.Assist finishing CTU RU of injector head,fill coil with brine,make up BHA and make up injector.(Ready to go in hole this morning.) Remarks#2 Added lighting in hallway by pump-room.Worked on steam coils in mud pits.Adjusted flow meter in flow line.Trouble shooting and repairing NE derrick lights. Insulating steam lines in welding shop.Changing out shackles in derrick.Cleaning and painting. Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 15.0 3/11/2013 3/12/2013 Clean out well to bottom with coil to 11,010'(recover 3 bbls of asphaltine over shakers).Pump hi-vis sweep,displace well with 10.3 ppg CaCl2 Brine while POOH(kill fluid for impending workover).Mill had no signs of wear.RD&prep to skid to C24-26.Rig released from C34-26 at 2400 hrs. Skid rig over C24-26. Remarks#2 Trouble shoot&work on derrick lights.Insulate steam lines in weld shop&pump room. Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 16.0 3/14/2013 3/15/2013 Build 350 bbls of 10.3 ppg CaCl2 brine.Kill well pumping thru GLV#8 at 9835'@ 5bpm 1200psi DP pressure holding 350-100 psi back-pressure on casing.Monitor well annulus dead,DP 70psi-brine out of balance. Remarks#2 Install handrails.RU 4"&6"return lines,4"mud line.RU hoses to wellhead in preparation to kill well. Construction Summary#3 www.xtoenergy.com Page 3/7 Report Printed: 9/10/2013 • wily Activity and Cost Summary_se ;fir°:NEli(.i1' Well Name: Middle Ground Shoal C34-26 API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200930000 TO8N-R13W-S23 Middle Ground Shoal 168-019 Alaska Directional Original KB Elevation(ft) ,Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 1 0.00 105.00 1 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 17.0 3/15/2013 3/16/2013 Spot 10.3 ppg CaCl2 brine pill in tubing.Monitor well.OK.Set BPV.N/D and set out tree.N/U Riser& BOPS.R/U test equipment and test BOPS.Had to Pull BPV and set 2 way check valve during test. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 18.0 3/16/2013 3/17/2013 Cont•testing BOPS.Pull 2 way check valve. MU lubricator&RUPollard E-line.RIH w/Radial Torch Tbg Cutter&Collar Locator.Cut Tmaming @.,__,. 9,860'.RD Pollard...-. Back out Tbg Hanger Lock-down screws.Pull hanger to rig floor, 107K Up Wt..Monitor well-OK. POOH laying down tubing,checking for NORM.Small amounts of asphaltine on tbg ID,otherwise in good condition. First 30 joints had some scale build up on OD. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 19.0 3/17/2013 3/18/2013 Conti POOH.laying_.down.ubing..jtntal 371 jtc tithing ping nrtt-off) Found two 1/16"holes in cut-off joint. NORM readings did not exceed 1 mR/hr. Install kelly spinner. MU 3.562"I.D.x 6"O.D.Hollow mill and 7"casing scraper BHA.RIH U 8,025',P/U DP U 8,211'.AC power outage 1 hour.Cont.P/U DP t/8,550'. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 20.0 3/18/2013 3/19/2013 Cont.P/U DP t/9,847'.Wash&ream. Tag tbg stub @ 9,883'drillpipe measure.Wash t/9,892'.Up Wt.182k,Rot Wt 147k,Dn Wt 127k,Torq 5k,650psi @ 140 gpm.Pump Hi-Vis sweep,2650psi©290 gpm.@ 15 gallons of scale in returns. POOH&LD BHA. MU RTTS packer&RIH._Set @ 9,855'.Test casing to 2000oiler 3,Q.r„n_nutes_OK.POOH. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 _l+-''t. 21.0 3/19/2013 3/20/2013 Test RBP to 1,000 psi,test good. Top sme with sand TOOH and UD cutter BHA.Drain stack and.N0 BQPE.Pull well head and 20'7" , csg.Continue to ND riser and remove old valves from well head room.NU 11"3K x 13-5/8"5K wellhead,NU BOPE and center on hole.Make up TAM inflatable packer and RIH to 45'MD.Drop ball and set packer. ,hest wellhead to 2,.QQQ,Q j fQr 31 minutes.test good.Change rams to 7"and RU to test rams. Remarks#2 Accident:While taking off the last nut on the pipe rams,Adrian Zimmer smashed his left index finger below the first joint.The reason for the smashed finger was the rams were opened before the nut was off.Mis-communication was the main reason the rams opened.We immediately brought Adrian inside and cleaned the finger and iced the same,we then laid him down and elevated his hand above his heart and covered him with blankets.His condition is good and his color in his face remains stable.We are waiting for the helicopter.The accident happened at 04:30 and we called for the helicopter at 04:50. Construction Summary#3 www.xtoenergy.com Page 417 Report Printed: 9/10/2013 D• aily Activity and Cost Summary_se ENERGY Well Name: Middle Ground Shoal C34-26 API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200930000 TO8N-R13W-S23 Middle Ground Shoal 168-019 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date iTotal Depth(ftKB) 105.00 0.00 105.00 1 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 22.0 3/20/2013 3/21/2013 SD for accident investigation Resume ops @ 11:3QQ Cont„chay t s t 7"^Tpsteo rams(Qi). RIH with ITCO spear w12"ID and engage the top of 7"casing.PU 10,000#over string weight. RU Weatherford and Pollard WL.RIH w/string shot and CCL.Shot off with 2500#torque at collar at 169',attempted to back off csg.Recharged Pollard and shot off with 4,000#torque.Backed off and pulled fish out.Measured fish at 102.88'with two joints and a stub.Prepare deck and floor to RIH with 7"sleeve and new casing. Plan forward:PU guided skirt joint w/2 regular joints of 7"26#L80 BTC-M.Slip skirt over and MU.Test casing for 30 minutes at 2,000 psi.Bleed off pressure and RD BOP's.Hang off 7"on slips,cut and install new Cameron tubing Spool.NU BOP's with VPR's for 2 3/8"&3 1/2",pressure test BOP's.RIH and wash off sand and retrieve 7"RBP.Measure 2 3/8"4.7#L80 8rd EUE tbg.RIH with tubing according to plan. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 23.0 3/21/2013 3/22/2013 ND flow nipple and send to welding shop.PU 7"casing skirt.RIH with 7"casing,pick up landing joint and hook up swivel.Swivel failed to rotate,removed hose and fixed swivel.Attempted to tie in 7"with overshot.Could not get skirt over csg.TOH.The skirt was riding on the collar.Modify the skirt and try again.RIH to top of 7"collar and got over same.an¢ rg.wr ,into he collarYulled up to 250K to make sure of connection.Rig up and pressure test against RBP to 2,000 psi for 30 minutes(OK).Drained stack and ND DSA from wellhead and raised riser to set slips.Pulled over 100K and set slips.Cut 7" casing.Lay down cut casing,blow down surface lines,rig down Weatherford tongs.Nipple down BOPE,Install tubing spool on WH. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 24.0 3/22/2013 3/23/2013 Cont.install new tubin s ool.Test to 3K,test good. RUBSPrrailie out pipe rams#or 2-7"x 3-1/2"VPRs.Test 250 psi low and 5,000 psi high for 2-3/8"and 3-1/2".Test annualr to 2,500 psi.All tests recorded OK.Rig down testing equipment and blow down lines. PU RBP running tool and TIH to 1094'MD.Wash sand off plug.Latc and release RBP.Monitor well: static.POOH and lay down RBP. Clear floor and PU 2-3/8"tbg handling equipment.Prepare floor and deck to PU completion string.Start to PU 2-3/8"4.7#L80 8rd EUE tbg w/7"retrievable packer and gas lift design as per production procedure. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 25.0 3/23/2013 3/24/2013 Continue RIH 2-3/8"4.7#L80 8rd EUE completion as per production procedure. At 2165'the string started to take weight and we rigged up to circulate out the obstruction.Could not circulate past 2165'.Broke out circulating swage and try to work down completion string without success.TOOH and found packer to be partially set on the bottom portion.Sent packer to shop for repairs. Contacted Lou Grimaldi of AOGCC to requested witness for BOP test.Witness was waived.RU testing equipment and test BOPE with 3-1/2"and 2-3/8"test joints.Tests were charted and tested at 250 psi low and 5,000 high.The annular was tested 250 psi low and 2,500 psi high. Waiting on packer(scheduled to arrive on 1st helicopter in morning). Remarks#2 Construction Summary#3 www.xtoenergy.com Page 5/7 Report Printed: 9/10/2013 Itaily Activity and Cost Summary_se ENERGY Well Name: Middle Ground Shoal C34-26 API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200930000 TO8N-R13W-S23 Middle Ground Shoal 168-019 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date ,Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 26.0 3/24/2013 3/25/2013 Waiting for helicopter to bring packer.Packer arrived at 08:30. Pick up packer and RIH with 2-3/8"4.7#L80 8rd EUE tbg&gas lift completion as per production procedure.RIH to 9,539'.RU Pollard and install Baker TE5 SSSV.Continue RIH to 9,888'. Plan ahead:Before landing,RU slick line and make dummy run to check depth and 3 1/2"to be open to well bore(not on procedure,approval by Engineer).Space out and land new tubing hanger.RU SL and lubricator and test to 4,000 psi.Finish completion as per production procedure and prepare to move to C24-26RD. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 27.0 3/25/2013 3/26/2013 Continue running 2 3/8"4.7#L80 8rd EUE tubing.Pick up landing joint and tag @ 9896'.Rig up slick line RIH with 1 3/4"tapered drift to verify clearance,check was good.RD SL and space out to land, terminate control line and test to 5,000 psi.Rig up and circulate packer fluid.Drain and lock down hanger.RU SL and RIH to verify.NO go at 1,392'WL depth.attempt to fish on wire,no good.Unlock hanger and reverse out and circulate 2X tubing volumes.Pump new packer fluid pill.Monitor well.Well is static.Land hanger and lock down.RU SL and verify position,good.RIH with PXN on wire.Attempt to set packer,returns through annulus.POOH with wire,RU rig mud pumps to set packer. Plan ahead: Set packer and test for 15 minutes.Set BPV and ND BOP's.NU wire line with new tubing head.Pull BPV and set 2-way check.Test WH to 5,000 psi.Pull 2-way check.RU SL,RIH and pull PXN.RD PWO gas lift.Move rig to C24-26RD. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 28.0 3/26/2013 3/27/2013 RU rig pumps to set packer.No go.RU slick line,RIH and retrieve PXN.Inspect PXN and dress for next run.RIH with PX plug on wire to test the integrity from the packer up.Test the tgiaact1tQIn to 2(M.,. psi for 15 minutes.test was good.POOH with PX.Dress up PXN with all new o-rings.RIH with PXN and ressure u to setpackel...pAsyjsi not visaed LAOS)Rsi•POOH with wire line and RD. Prepare to 11pu compretion string.Drain stack,unlock hanger and pull same.Monitor hole.Hole U-tubing.Weight up mud in pits to 10 lb/gal and displace hole.Monitor well. Plan ahead:POOH with tubing to packer.Take off packer and send to the shop for repair.Get packer back and install in string,PU tubing and trip back in hole.Follow completion procedure. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 29.0 3/27/2013 3/28/2013 Finish displacing well with 10.0 ppg MW.Shut down and monitor well,Static.POOH with completion tubing from 9848 to SSSV,rig down Pollard,all 29 clamps recovered.Continue to POOH and lay down all joints.Take off packer and load the packer and XN nipple on boat to take to shore and send to the shop for repair.Clean rig floor,service tubing tongs,pick up kelly to service.Do all maintenance on rig while monitoring well on TT.Well is static. Plan ahead:Re-install packer and TIH with all the completion string.Space out and place packer fluid. Run in lock screws.RU slick line to verify the SBR is stabbed into 3 1/2"tubing sub.Set packer,test. Finish well according to production procedure. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 6/7 Report Printed: 9/10/2013 "tally Activity and Cost Summary_s s E ERR Y Well Name: Middle Ground Shoal C34-26 API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200930000 TO8N-R13W-S23 Middle Ground Shoal 168-019 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 Daily Operations y Rpt No. Report Start Date Report End Date Operation Summary#1 30.0 3/28/2013 3/29/2013 Waiting for packer.Repair kelly spinner air valve. Picked up TIW SBR and packer and started tripping in hole with production tubing as per Oglenook Rep to 8814".Picked up SSSV and rigged up Pollard to make up control line.Finish completion to 9,848'and space out to land.Make up hanger as per Cameron.Spot packer fluid,Land and lock down hanger. Plan ahead: RU slick line to verify the SBR is stabbed in to 3 1/2"tubing stub.RIH with PXN plug and set XN nipple.Pressure test and set packer.Hold 4,000 psi for 30 minutes and chart the same.Finish completion as per production procedure.Prepare to move to C24-26RD. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 31.0 3/29/2013 3/30/2013 RU slick line,RIH with tapered drift on wire to 10,000'WLD with no problems.POOH with same.RIH with PXN on wire and pressure up to 4,000 psi in increments to set packer,test for 30 minutes.Test was charted and good.Lay down landing joint and set BPV.Nipple down BOPE.Assist Cameron to nipple up tree and test to 5,000'psi.Test was good.Finish well at 24:00 hrs and get ready to move to C24-26RD Remarks#2 Construction Summary#3 www.xtoenergy.com Page 7/7 Report Printed: 9/10/2013 taily Activity and Cost Summary_se Aes Well Name: Middle Ground Shoal C34-26 APINWI Location Field Name Permit Number State/Province Well Configuration Type 50733200930000 TO8N-R13W-S23 Middle Ground Shoal 168-019 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 Jobs Job Category Primary Job Type/Initial Job Type Secondary Job Type/Final Job Type Start Date End Date Well Maintenance Pull Tubing 4/28/2013 00:00 6/5/2013 12:00 Objective Repair 7"Casing leak Summary Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 1.0 4/28/2013 4/29/2013 RU slick line and run in hole to bottom GL mandrel @ 9,700'MD.Test mud lines to 2,400 psi,check for leaks at choke flow lines.Prepare to rig up and kill well with with 10.3#/gal CaCl2.Pull out of hole with valve,rig down slick line.Kill well with 10.3#/gal CaCl2.check well for flow,well no flowing.Set BPV, ND Well head.NU riser and BOPE.Test BOPE.250 psi/5,000 psi with 2 3/8"&3 1/2".2,500 psi on Annular preventer.Blow down lines and rig down testing equipment.Pull 2 way check.Rig up&pull hanger;8 bbls to fill hole:Attempted to sheer packer,Not able to sheer at 80%of tubing strength. Called XTO engineer to possibly increase pull to a higher number.Decided to keep working pipe at current rate in attempt to weaken shear screws. Plan ahead:If packer does not release,Bring out Pollard unit to cut tubing.Send out overshot tools with jars from Olgoonik to jar on the fish and POOH with the fish. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 2.0 4/29/2013 4/30/2013 Attempting to release packer without any success.Cut and slip 224'of drilling line.Wait on work boat until)21:30.pick up and spot E-line on cat walk.Rig up Pollard to cut tubing.Pull 15 K over on tubing and RIH with tubing cutter on E-line and cut tubing at 9,751'wire line depth.POOH witn E-line and rig down.Monitor well.Well was static,POOH with completion string and lay down joints of 2/38"tubing. Plan forward:Contonue laying down 2 3/8"tubing.Pick up overshot assembly with DP and TIM. Connect with fish and jar the packer loose.POOH with fish.Make up Halliburton 7"RBP and RTTS. TIH and set RBP at 9,750'and Rtts at 5,000'to pressure up and find leak. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 3.0 4/30/2013 5/1/2013 RIH w/E-line and cut tubing @ 9,751'.Monitor well(static).POOH and lay down tubing.M/U Overshot assembly&RIH,Tag fish @ 9,742 SLM.Latch onto fish.Work free w/80k over-pull,jarred one time. CBU. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 4.0 5/1/2013 5/2/2013 Continue CBU.No gas.Monitor well(static).POOH&LID Fish,M/U 7"RBP&7"RTTS. RIH.Attempt to set RBP between 9750'and 9880'.Would not set. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 5.0 5/2/2013 5/3/2013 After attempting to set RBP between 9750'and 9880'&would not set.POOH to inspect RBP-Threads had backed-off at top of by-pass mandril(Left By-pass,RTTS, 1 jt.DP,Retrieving overshot and RBP in hole).RIH w/overshot.Catch fish @ 9837'.RBP stuck.Attempt to work free.Release RBP Retrieving tool and POOH.Retrieved By-pass,RTTS, 1 jt.DP and Retrieving tool.RIH w/RBP Retrieving tool& jars. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 115 Report Printed: 9/10/2013 . frogaily Activity and Cost Summary_s E IzHtiI Well Name: Middle Ground Shoal C34-26 API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200930000 TO8N-R13W-S23 Middle Ground Shoal 168-019 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 Daily Operations 7. ''; Rpt No. Report Start Date Report End Date Operation Summary#1 6.0 5/3/2013 5/4/2013 Cont.RIH w/Retrieving tool.Engage RBP.Pull 15k over-pull.Set 30k on RBP cycle to un-set position. Pick up with no over-pull.POOH to examine RBP.Rebuild RBP.M/U RBP&RTTS assembly and RIH. Set RBP @ 9,768'.Set RTTS&Test RBP t/2000 psi.Stage out of hole testing casing(checking for leak. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 7.0 5/4/2013 5/5/2013 Cont.stage out of hole testing casing for leak w/RBP©9,768'. Last test 189't/9,768',2000 psi for 20 minutes no bleed-off.(Previous Tie-back was made©169').POOH lay down RTTS.RIH and retrieve RBP.POOH.Set RBP©911'&POOH.M/U RTTS,RIH&set RTTS @ 400'.Test RBP t/2000 psi for 10 minutes. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 8.0 5/5/2013 5/6/2013 Spot 500#of sand on RBP POOH w/RTTS.M/11,7"casing cutter.Cut casing©180'.Displace gas& ca 9.1 mud out of 10-3/4"casing.LID Csg cutter.N/ BOPs.LID 7"csg.N/U BOPs.Install 7"pipe rams. Test Rams and all breaks 250/3000 psi. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 9.0 5/6/2013 5/7/2013 Test Annular to 250/2500 psi.M/U Casing spear.Engage spear©211',put 3500ft/lbs left-hand torque in casing,Fire string shot.Back-off casing.LID casing stub.M/U swivel on top joint of casing&UD in V-door.P/U skirted joint+5 other joints,Screw into casing at 211:&.torquato 8000 ft/lbs.Pull to 205k. Re-torque to 8000 ft/lbs(No additional make-up).Pull to 225k.Pressure test to 2000 psi for 30 minutes. P/U BOPs.Set casing slips w/170k casing weight.35k over-pull.Cut csg.Set out BOPs.Install tubing spool.Test spool U 3000 psi, Remarks#2 ` ,---(" '- t` Construction Summary#3 -. Rpt No. Report Start Date Report End Date Operation Summary#1 10.0 5/7/2013 5/8/2013 Cont.N/U BOPs&Test w/2-3/8&3-1/2 Tubulars. RIH t/911',Circ out sand&retrieve RBP.M/U 3-1/2" hollow mill&RIH. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 11.0 5/8/2013 5/9/2013 Cont.RIH U 9,872'and Polish top of Tbg stub f/9888'-t/9895'.R/U Slick line&RIH w/to verify entry into 3-1/2"tbg. R/D slick line.POOH w/mill.Pull wear ring.Run completion tbg per prog. to 5,083' Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 12.0 5/9/2013 5/10/2013 Cont.run tbg.Stab SBR over stub @ 9872',R/U Slickline&RIH w/1.70 Tapered Drift to verify entry into 3-1/2"Tbg.Space out hanger.Pump packer fluid.Land tubing hanger.SBR©9,876'. R/U Slickline &RIH w/1.70 Tapered Drift to verify entry into 3-1/2"Tbg.Set plug in XN Nipple©9,864'.Test Tbg U 1000 psi.Set Pkr.-set @ 2200 psi.Test tbg U 4000 psi.for 30 minutes.Test Annulus U 2000 psi for 30 minutes. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 2/5 Report Printed: 9/10/2013 gaily Activity and Cost Summary_s f rill Y Well Name: Middle Ground Shoal C34-26 API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200930000 T08N-R13W-S23 Middle Ground Shoal 168-019 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) ,Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 13.0 5/10/2013 5/11/2013 Retrieve XN Plug.LID Landing Joint.Set BPV.N/D BOPs&Break bonnet on Hydril to replace element. N/U Wellhead.Pull BPV&Install 2-way check.Test Wellhead t/5000 psi for 15 minutes.Pull 2-way check. 3-1/2"Tubing Stub 9,872'(Tagged w/DP @ 9,887') SBR @ 9,876' XN Nipple @ 9,863' Pkr @ 9,741' X Nipple @ 9,696' SSSV @ 317' RKB @ 32.47' 22 SS Bands on Control Line Rig released at 1200 hrs to C24-23 Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 14.0 5/23/2013 5/24/2013 Move rig over well.Swap hatch covers with C24-23.Move jacking system to other side of rig.Prepare to continue to move rig to leg 1.Run all electrical wires,replace hand rails,install 4"mud line.Install mud dock.organize upper deck to skid rig to the center of the well.Test mud lines to 2,500 psi and check for leaks.Secure storm clamps and finish rigging up on well.Inject mud from pits and prepare to mix mud to kill weight at 10.3 ppg. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 15.0 5/24/2013 5/25/2013 Continue moving rig and setting up on well.Function test all assignments on both generators. Electrician to troubleshoot ground fault,continue to inject 263 bbls from pits,organize top deck,spot catwalk.Rig up slick line on well,RIH to pull orofice valve at GLM 9,700'MD.Pull out of hole with orifice and rig down slick line tools and equipment.Make up 2 3/8"handling equipment.Rig up lines to kill well,taking returns to production header.Pumped 146 bbls.Swaped over to pits for returns through choke at 1.5 bpm and 630 psi. Plan forward:Finish killing well.Monitor well for 1 hour,Nipple up and test BOPE.RU E-line and TIH with radial cutter to cut tubing.Pull out tubing and lay down the same. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 16.0 5/25/2013 5/26/2013 Continue killing well procedure.Monitor well for 1 hour.Rig down circulating manifold.Have Cameron set BPV and start nippling down tree.Nipple up BOPE,pressure up Accumulator and function test stack.Make up test joint and prepare to test BOPE.Witness was waived by Bob Noble from AOGCC. Test Bope with 3 1/2"&2 3/8"test joints:250 psi/5,000 psi;Annular Preventer 250 psi/2,500 psi. Continue testing BOPE and Kelly valves,draw down test on Accumulator.Pull 2 way check and fill hole: took 36 bbls total to fill.3 bbls/hr losses calculated to hole.Unlock hanger and pull 15K over string weight;rig up E-line unit and RIH with jet cutter;Cut tubing @ 9,734'WLD.POOH with same and rig down E-line tools and equipment.Prepare deck to lay down completion tubulars and Gas lift mandrels. Plan forward:Lay down 2 3/8"tubing.Pick up overshot fishing tools and TIH to retrieve packer. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 3/5 Report Printed: 9/10/2013 tally Activity and Cost Summary_s F Ni H(j ' Well Name: Middle Ground Shoal C34-26 APINWI Location Field Name Permit Number State/Province Well Configuration Type 50733200930000 TO8N-R13W-S23 Middle Ground Shoal 168-019 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 17.0 5/26/2013 5/27/2013 Continue TOOH with E-line.Flow check well:3 bbls/hr losses;Prepare floor to lay down tubulars.Gas in mud,circulated 2 times bottoms up through choke.Shut down when 10.3 ppg was in and out. Monitor well for 1 hour.Well was static.Pull out of hole laying down tubing and marking each joint and checking for unusual wear while laying down.Prepare rig floor to pick up new BHA and DP off of cat walk.Start picking up fishing BHA as per Oglenook representative.Strap and drift collars,HWDP,and DP while going in hole to pull Packer. Plan ahead:pull out packer and send to town to redress.Pick up 7"23#RPB and RTTS to RIH and check for leaks. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 18.0 5/27/2013 5/28/2013 Continue to lay down 2 3/8"tubing.Rig down tubing handling equipment.Strap 4 3/4"DC and HWDP and DP,install wear ring.Pick up new BHA with overshot and jars with Collars,HWDP and DP while TIH.Tag Fish and work grapple over fish.Pull 60K over string weight and set jars off.Repeat same procedure until packer releases.It took 3 times before packer released.POOH with packer assembly on.Lay down packer assembly and send packer to town to be redressed. Pick up 7"RBP and RTTS on drill pipe with appropriate tail pipe.RIH to 270'and set RTTS to test above at 2,000 psi for 30 minutes.Chart the results. Plan ahead:Continue following procedure for RTTS and RBP.When leak is determined,make cut below the first collar and POOH. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 19.0 5/28/2013 5/29/2013 Cont.POOH&L/D fish(Pkr&Tubing Tail). M/U RBP&RTTS BHA,RIH U 270'.Set RTTS&test casing to surface to 3000 psi.for 30 minutes(Bled 25 Ibs). RIH U 9764',Set RBP,Set RTTS @ 9750'Test RPB,OK.Test csg to surface U 2000 psi,OK. POOH Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 20.0 5/29/2013 5/30/2013 Cont.POOH U 4754',Set RBP,Test casing U 2500 psi.OK POOH U 1050'.Set RBP.Test casing U 3000 psi.OK Spot sand on RBP&POOH Cut casing©232'(21 below tie-back) N/D BOPs and Tubing Spool M/U Spear,retrieve casing and L/D same,Recovered 201' Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 21.0 5/30/2013 5/31/2013 N/U BOPs and install 7"rams Test 7"Rams and Connection breaks Run 7"patch&casing and test,Pull U 200K string wt.,40k over-pull,Test U 3000 psi,No apparent leak, P/U BOPs,set csg slips w/200K, Test casing U 3000 psi,Leaking 140 psi in 60 minutes,Pull to 325k and remove csg slips,Pressure U 2535 psi,Patch came lose. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 4/5 Report Printed: 9/10/2013 Sally Activity and Cost SummarylIP t ENERGY Well Name: Middle Ground Shoal C34-26 API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200930000 TO8N-R13W-S23 Middle Ground Shoal 168-019 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 105.00 0.00 105.00 Daily operatkms. Rpt No. Report Start Date Report End Date Operation Summary#1 22.0 5/31/2013 6/1/2013 N/U BOPs, POOH w/Patch, Install VBRs and test U 3000 psi. RIH U 250'w/RTTS and test Csg&RBP @ 1050', RIH&Cut casing @ 278' Retrieve casing-casing split&a 4"triangle piece missing from top of casing, Repair Iron Rough-neck(electric cylonoid) UD Spear&40'of casing- RIH and polish top of casing Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 23.0 6/1/2013 6/2/2013 Install 7"Rams&test U 250/3000psi RIH w/Casing Patch and engage casing©278',Pull test to 250k,Test Casing U 3000psi(OK),Set csg slips w/175k(10k over-pull)Re-test csg U 2000psi(OK),Cut csg&N/D BOPS,N/U Tubg spool Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 24.0 6/2/2013 6/3/2013 N/U Tubg spool&BOPs,Install VBRs&Test Rams and connection breaks U 250/5000psi,Make 4 Magnet runs to top of sand on RBP @ 1034'(UD drillpipe each trip out), RIH w/Retrieving Tool,CBU 2X,Retrieve RBP,UD BHA on trip out,Pull wear ring.Test BOPs. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 25.0 6/3/2013 6/4/2013 Finish BOP test.Run 2-3/8"completion Tbg.U 9,891'.R/U Slick-line and RIH w/1.70 drift to verify entry into 3-1/2"Tbg. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 26.0 6/4/2013 6/5/2013 Space-out and M/U hanger,Terminate control line for SSSV.Spot 20 bbls of packer fluid.Land hanger &lock-down. Up wt 61k,Dn wt 51k.R/U slick-line and set plug in XN-Nipple©9,878'.Set Pkr @ 9,751'w/1350psi., Test Tbg U 4000psi.(Leaking out annulus),Pull slick-line out of hole,reverse circ thru GLMs,Retest (leaking out annulus),Change out Orifice Valve,Retest(No leak on annulus,pressure still dropping 200psi in 4 min.)Change out plug in XN-Nipple,Retest(No leak on annulus,Pressure still dropping 700 psi in 3 min.)Test Pkr&Annulus U 2000psi,No bleed off.Pull prong&plug from XN-Nipple,Set BPV, N/D BOPs Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 27.0 6/5/2013 6/6/2013 Cont.N/D BOPs.N/U wellhead&Test U 5000psi.,Pull 2-way check,Turn over to production,Prep to Skid rig U C24-26RD. Released Rig to C24-26RD at 1200 hrs Remarks#2 Construction Summary#3 www.xtoenergy.com Page 5/5 Report Printed: 9/10/2013 &G, C 34- • • Iwpotco Regg, James B (DOA) From: Alaska_Drilling @xtoenergy.com Sent: Sunday, May 26, 2013 6:47 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: Fw: BOPE TEST 26 May 2013 C34 -26 Attachments: 5- 26- 13.xlsx; BOPE Test Chart 1 5 -26 -13 001.jpg; BOPE Test Chart 2 5 -26 -13 001.jpg ✓ Jim, Here is the results of our BOP tests with charted results on C34 -26. Lonnie Drollinger Platform C 907 - 776 -2534 Forwarded by Alaska Drilling /KEN /CTOC on 05/26/2013 06:41 AM " Toolpusher" a offshore (a) allamericanoilfield.com> To Alaska Drilling /KEN /CTOC cc 05/26/2013 06:39 AM Subject BOPE TEST 26 May 2013 Richard J. Kerr SCANNED MAY 3 0 2013 ALL AMERICAN OILFIELD 907.299.1041 XTO Platform C 907.776.2535 o ffshore pallamericanoil field. corn 1 • • • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report •Z1 i (Z.k' Submit to: jim.regq a�.alaska.gov I I AOGCC.Inspectorsaalaska.gov phoebe. brooks(D,alaska. gov Contractor: All American Oil Rig No.: XTOC DATE: 5/26/2013 Rig Rep.: Edmonson / Kerr Rig Phone: 776 -2535 Rig Fax: 776 -2536 Operator: XTO Energy Op. Phone: 776 -2534 Op. Fax: I Rep.: Lonnie Drollinger E -Mail alaska_drilling©xtoenergy Well Name: MGS C34 -26 PTD # 1680190 - Operation: DrIg: Workover: X Explor.: Test: Initial: X Weekly: Bi- Weekly Test Pressure: Rams: 250 / 5000 ' Annular: 250 / 2500 - Valves: 250 / 5000 ' MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. NA Ball Type 1 P Standing Order Posted P Misc NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" P Pit Level Indicators P P #1 Rams 1 2 -3/8" X 5" P Flow Indicator P P #2 Rams 1 Blind P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 -1/8" P Inside Reel valves 0 NA HCR Valves 1 3 -1/8" P Kill Line Valves 3 2- 1/16" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time /Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 1700 P Quantity Test Result 200 psi Attained 33 P No. Valves 14 P Full Pressure Attained 151 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles (avg): 6 © 2375psi CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 - Test Time: 7.0 Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors @alaska.gov Remarks: All Good Tests With 2 3/8" & 3 1/2" Test Joints - 24 HOUR NOTICE GIVEN YES X NO Waived By Bob Noble Date 5/23/13 Time 05:13 AM Witness Test start 1800 Finish 0100 Form 10 -424 (Revised 03/2013) 2013- 0526_BOP XTOC MGS • • BOPE Test Charts Rig XTOC (XTO Energy Inc.) — MGS C34-26 5/26/2013 Pri\ /t °trio 4000000.•••••• 6 Am 7 1 -- ----_____ ?4,_ ---- / - `, ---, .--, 0 .-....... o - F/ / / 7" 0 - - 0 0.19"..r •--. - \ -----\ / X 't'°° \ ' 4 <.? N \ „,•\ '''' \ ‘ / de\ _ , ' - '' .■„, , ____„ . 1 / ; \ ./ \ ' --\ , V / 0\ -------f-------4_ „„ ,0 , ,,... , / e0 \ i. . - -,. /-\\/ / / 0 / ° O ' , .•,,- 1 * ,, \ ' e t- - v " ' ‘ r / or fo, ■k Coofi I # . , \ , / \ ' S. CHART Na ... \ ' ----- .■---- t 1 fmEreR [-IC MP-10000 r- 0 '5 "Z 7 ._ ___,__ _ ,,_.1- PT PUT ON . . ■ c ''. ' 2...c PIA y 20,5 , K./- N OFF I ..,' I 1 ----- ' \ OCA1,0. " 1 1 A' \ REmARK j--- \ \ - Mit !irk a w 7 - . - ' I \ - A --I— , \ \ V .... • esr , 1 A , 0 , \ 62., .- \------ \ \ \ z \ 7 0 ' - - 0 , ,.. \ , N. - ' \ \ - ''' - ` / ....x „,,, \ \\ ---' \ )9 1 6: //, ' / 0 / , ,,. .• --Z / .-------- . <-', , ,, / ',, ,,,,/ / \ \ N „;- ., .*,,' \ \ y '' - ---, .'l -- ------_-_ _ - 1 __ ° °0, 9 '------- \ \ \ x ------„, -- i -, 0 0o, ---,,,,, -------- ----- ___..--- ,..---- 7 9 -------1-111------- ';--- ■•.1 9 _ Page 1 of 2 • • • 5 " nip ,.,, ._z _ liner . ' ' B ' • 1T tj � < @ 000 C . ( /...--/' ' S/ ppp O J• 0 11#"."....." '''' . - '''' 1- .. r ,„, c - - , , ,. ' 1 e j • G , 4 b Opp • r -14 ■41 s Syri ; ,•,), N„\....:, , \ ',,, -- \ \ ,, 2-__,-----,,--- . C HART NO. MC MP -10000 o c� o c .p ....,C1 - O 0 4 ------ � i METER _� i I +__. _. O - � 1�- `' --- .._. _ CHART PUT ON T AKEN OFF a '� I 1 i ' 0 0 _ o s, 0 0 ° 5 2013 2li MAy2Ul3M .� • 1 0 ° ° o. ° LOCATION M6 Cg - 24 pacirMN t \ �r-' � _ REMARKS 'throw_ sok ms � � � i '�-� . `''.. 1 • i \ \ , .1, -:,,,,,\\,-"'-- \ \ ''''')/ / ' t i . ,, , ,,,/ , .,* / .j: ' 410, ' ' t � � XJ `` . ,\/ 0 / Y , • Y. •. `¢ 1\X /; / � i " 'III, -- \ 00 � t ! S /i �' N Opp _� a ' � � , . i � ,�,''�/ J � i ,i • Opp / ": ",- / y N \ isb --- — Page 2 of 2 OF T�J Alaska Oil Gas //7, , THE STATE �`� � ® f sKA Conservation Commission ��,, GOVERNOR SEAN PARNELL 333 West Seventh Avenue ® F ALAS� Anchorage, Main: 907.279.1433 Fax: 907.276.7542 Bola Adeyeye SC ►NNE© Operations Engineer XTO Energy I 9127 S Jamaica St � Englewood. CO 80112 l� Re: MGS Field, E, F, G Pool, MGS C34 -26 Sundry Number: 313-258 Dear Mr. Adeyeye: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / Cathy P. oerster Chair DATED this Z4 day of May, 2013. Encl. -, RECERIED STATE OF ALASKA f ' v ALASKA OIL AND GAS CONSERVATION COMMISSION AOGGO APPLICATION FOR SUNDRY APPROVALS 20 MC 25.250 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Paklmte Nee Pod ❑ Repair Weil (] - Change AptNevsd Prvgtanr 0 Suspend ❑ Plug Perforations ❑ Palmate ❑ Pill Tubing D ' Time Earsrtsan ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate [] Alter Casing © ' Other 0 2. Operator Name: XTO Energy 4. Current Weit Oese: 5 Penn! to Dril Numbe' Exploratory ❑ Development D • 16419 . 3. Address: 9127 S Jamaica St Stratigraphic ❑ Service 0 B. API Number Englewood, CO 80112 60 - 733 7. If perforating: B. Well Nanerand Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ Nn ❑ Midrffie Ground Shoal C34.26 . 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 18756 ' MGS E, F, G ' 11. PRESENT WELL CONDr11ON SUMMARY Total Depth MD (ft): Total Depth ND (fl): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,282 . 9,908 • 11,024 8,692 NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,732' 10 -3/4" 1,732' 1,642' 3,130 psi 1,580 psi Intermediate Production 11,259' 7" 1,259' 9,889' 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth ND (It): Tubing Size: Tubing Grade: Tubing MD (ft): 9,919 - 11,000 8,720 - 9,672 2-3/8" & 3-1/2' 1-80 & N-80 10,883 Packers and SSSV Type: 4 - 7" Guiberson Uni- Packer VII Packers and SSSV MD (ft) and ND (ft): 1 - 7" TIW HM-1 Retrievable Packer, 1 - Baker TE-5 SSSV Please see attachment 12. Attachments: Description Summary of Proposal p 13. Weft Class after proposed work: . Detailed Operations Program 1E1 BOP Sketch MI Exploratory ❑ Stratigraphic ❑ Development MI Service ❑ 14. Estimated Date for 5/24/2013 15. Well Status after proposed work Commencing Operations: Oil El ' Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bete Adeyeye Email aiibola adeveve(5)xtoeneray.com Printed Name Bole Adeyeye Title Operations Engineer Signature p Phone (303) 397 -3606 Date 5/21/2013 COMPASSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number i3 Z5 k Plug Integrity ❑ BOP Test ti Mechanical Integrity Test ❑ Location Clearance ❑ Other. , U / J /-1-5/- ?UG'U v /25, \� Spacing Exception Required? Yes ❑ No ( Subsequent Form Required: ` 4 0 ¢ RBDMS MAY 2 8 2(13 r f. �) _ APPROVED BY / Approved by: L, f " 4 / i�_,.__. COMMISSIONER THE COMMISSION Date:,,] - _- � / vL-? 5124/13 - (` ISSi7Alt 79 Form 10 Revised 10/2012 A i ///'''��� d A- i onths from the date of approval. roval. Submit I Form and ( ) Pll� (J�[ L PP Attachments In l)up6cate • • RECEIVED FNFRGV klAY 242013 AOGCC May 21,2013 Alaska Oil and Gas Conservation Commission Attn: John Norman, Commissioner 333 W 7' Ave., Suite 100 Anchorage, Alaska 99501 -3539 RE: Form 10 -403, Application for Sundry Approval Objective: Repair 7" production casing Middle Ground Shoal C34 -26 Middle Ground Shoal Field: E, F, G Oil Pools Cook Inlet, Alaska API: 50- 733 -20093 XTO Energy herby submits its Application for Sundry Approvals to repair the 7" production casing in the • Middle Ground Shoal C34 -26. Enclosed are the following attachments: 1. Form 10-403 Application for Sundry Approval 2. Form 10-403 Attachment (Packers and SSSV depths) 3. Summary Page 4. Job Procedure 5. Wellbore Diagram 6. Approved Sundry #312 -320 (original workover sundry) If you require additional information, please contact me at (303) 397 -3606. Sincerely, Bola Adeyey , 0 erations Engineer CC: Sandra Haggard, Regulatory Analyst, (303) 397 -3672 • • XTO Energy MGS C34 -26 Form 10 -403 Attachment Packer & SSSV depths Item MD (ft) TVD (ft) Baker TE -5 SSSV 293 293 7" TIW HM -1 Retrievable Packer 9,746 8,568 Guiberson Uni- Packer VII, #1 9,880 8,680 Guiberson Uni- Packer VII, #2 10,331 9,079 Guiberson Uni- Packer VII, #3 10,481 9,213 Guiberson Uni- Packer VII, #4 10,662 9,374 • • )(TO NFRCY May 21,2013 To: John Norman Guy Schwartz Victoria Ferguson CC: Scott Griffith Romeo Perez From: Bola Adeyeye RE: MGS C34 -26 Cook Inlet, Platform C 7" casing repair Addition to previously completed workover program XTO completed the workover on the MGS C34 -26 (Sundry #312 -320) to install a new gas lift . completion and return the well to production on April 5, 2013. When lift gas was injected down the 7" casing x 2 -3/8" tubing annulus, pressure began to increase within minutes on the 10 -3/4" casing x '7" casing annulus. Leak identified at tieback joint was fixed and well was returned to production. Subsequently after production resumed, pressure was still noticed on the surface casing, attributed to lift gas injection on the 7" casing x 2 -3/8" tubing annulus. Gas injection was stopped, the surface casing pressure was bled off, and the well was shut in. The well is currently . shut in and awaiting the testing and repair of the 7" casing. Although the MIT passed with fluid, pressure continue to build -up in surface casing at a slower rate when lift gas is injected. This indicates gas leak that could not be identified via fluid mechanical injection test. Casing will be cut below the leaking joint (possibly at 211 ft tieback depth), an overshot casing patch with external seals will be bowled over casing stub. The seals will ensure gas migration is prevented from 10 -3/4" surface casing. Please reference Sundry #312 -320 for the original scope of work, workover procedure; kill weight calculations, BOPE drawings, etc. A copy of the approved sundry is attached to this application for your reference. If you require additional information, please contact me at 303 - 397 -3606. Sincerely, w• Bola Adeye e Operations Engineer • • jfro Nr.HG XTO ENERGY MGS C34 -26 - EAST FLANK PRODUCER COOK INLET, ALASKA 7" CASING LEAK REPAIR 05/21/2013 WELL DATA SURFACE CASING: 10 -3/4 ", 40.5 #, J55, BTC set @ 1,732'. Cmt w /1,550 sk. LONGSTRING CASING: 7" 23 #, 26# & 29# N80. Set @ 11,259'. Cmt w /1,200 sk. TOC @ 7,900' Surface — 211': 26# (Buttress Modified Thread) 211' - 4711': 23# 4,711' — 8,646': 26# 8,646' — 11,259': 29# TUBING: 2 -3/8 ", 4.7 #, N80, 8rd, EUE ® 9,877' 3 -1/2 ", 9.3 #, N80, 8rd, EUE @ 10,683' PACKERS: 4 — 7" Guiberson Uni- Packer VII @ 9880', 10,331', 10,481' & 10,662' Guiberson packers set in 1973 1— 7" 11W HM -1 Retrievable Packer @ 9,762' set 05/8/2013 PERFORATIONS: GR -GS: 9,919' — 26' & 9,932' - 57' HC -HD: 10,247' — 56' & 10,284' — 305' HD -HE: 10,355' — 65' HE -HF: 10,397' — 453' HI -HK: 10,526' — 40' HK -HN: 10,547' — 644' & 10,690' — 752' HN -HR: 10,786' — 11,000' 1 of 4 • • FISH: 2' — 3 -1/2" tbg w /Q- Nipple @ 11,024' PBTD: 11,024' BHST: 170 Deg F BHP: f 4,500 psi (SI WHP = 500 psi) SMALLEST ID: 1.791" ID X Nipple @ 9,878' PRESENT STATUS: SI with 50 psi WHP and 380 psi CP OBJECTIVE: Repair 7" casing leak BACKGROUND: After 2' workover in a month to return this well to production (Sundry #312 -320, AFE #1200385), pressure was noted on the 10 -3/4" x 7" annulus when lift gas was injected down the 7" x 2 -3/8" annulus. However, the pressure observed was lower than the after the first attempt as repairing the casing. The 7" casing sufficiently passed fluid pressure test at 2000psi but gas seal- ability couldn't be accomplished during production. It is characterized as slower leak although unacceptable for optimum gas injection and integrity of the surface casing. The leak is most likely originating from approximately 211 feet, this is the back -off depth on the 7" casing after coupling string shot was performed during last workover. EQUIPMENT & MATERIALS REQUIRED: • 7" casing joint with casing patch overshot with seals (Baker Oil Tools) • Mechanical Cutter for 7" casing and associated BHA (Baker Oil Tools) • Washover shoe to dress 7" casing stub (Baker Oil Tools) • 7" RBP (Halliburton) • 7" RTTS packer (Halliburton) • 5 -3/4" Casing spear (Baker Oil Tools) • 10' Pup joint of 7" 26# BTC- Modified L -80 casing • 7 ", 26 #, L -80, BTC -M casing (TSA; exact amount will be dependent on location of leak) • New slips for 7" casing (Cameron) • 10.3 ppg CaC12 fluid (Adequately increase weight of leftover from C24 -23) 2 of 5 • • PROCEDURE: 1. MIRU derrick. 2. RU SL. RIH to bottom GL mandrel at 9,700'. Pull orifice valve. RD SL. 3. Kill well with 10.3 ppg CaCl fluid (weight up 10.1 ppg kill weight fluid used on C24 -23) by down tubing and circulating out tubing-casing pumping g g g g annulus. Monitor well to ensure it is dead. 4. Notify AOGCC 48 hours prior to BOPE test. Set BPV. ND WH. NU riser and BOPE. Pull BPV and set two -way check. Ensure that BOPE has VPRs for 2 -3/8" — 3 -1/2" pipe. Pressure test BOPE to 250 psi and 5,000 psi. 5. RU to POOH and LD 2 -3/8" gas lift completion. Release packer. POOH and LD 2 -3/8" tubing with gas lift valves. Send packer to onshore to be redressed. 6. MU 7" RBP and 7" RTTS on 3 -1/2" 15.5# drill pipe and appropriate tail pipe to provide adequate setting weight. RIH to 270' (1.5 joint below back off depth at 211') and set packer. Do not set RBP at this depth. Test above to 2000 psi, hold pressure and chart for 30 minutes. 7. Repeat pressure test at 2500 psi and chart for 30 minutes. If pressure drop greater than 10 percent is not observed, contact Bola Adeyeye to discuss option of increasing the test pressure. 8. Unset the packer and continue RIH. Set RBP at 9762' (same Iocation as the production packer). Pick up 1 joint, set RTTS packer and pressure test RBP to 2000 psi, insuring bridge plug provides isolation. Release RTTS and pull up hole to 5000' and set packer. 9. Pressure test between RTTS and RBP to 2000 psi for 30 minutes. Pressure test from RTTS to surface to 2000 psi for 30 minutes; increase pressure to 2500 psi for above the RTTS and hold for 30 minutes. Chart all pressure reading. 10. If test from 5,000' to surface fails, release RTTS, PUH and reset RTTS at 2,000'. Test below the RTTS packer to 2000 psi, hold and chart for 30 minutes. Test above the RTTS to 2500 psi, hold and chart readings for 30 minutes. Continue moving RTTS half way up -hole and retesting until the leak is located. Test below the RTTS to 2000 psi and above packer to 2500 psi. Do not exceed 2000 psi when testing below the RTTS packer. NOTE: If pressure test below 5,000' fails, continue moving packer down hole and pressure testing to locate the leak. Once the leak is located, stop before proceeding. Contact Bola Adeyeye before moving forward. 11. RIH to RBP. Release RBP. PUH and reset RBP 1.000' below the casing leak. Drop 500 lbs sand on top of RBP. POOH with drill pipe and RTTS. 3 of 5 • . 12. If leak depth is shallow (less than 300 ft), MU 7" casing cutter on DP. RIH and cut 7" casing approximately 6 ft below the coupling of the leaking joint. If leak depth is greater than 300 ft, cut 7" casing 40' below the wellhead assembly (cut must be BELOW the first collar so that the slips come out with the collar). POOH and LD casing cutter. 13. ND BOPE. ND tubing spool. 14. Pick up 5 -3/4" Bowen spear, bumper sub and appropriate BHA to pull out casing stub. Record the pickup and slack off weight. Engage cut casing, pull out of hole while laying down the casing. 15. NU 13 -5/8" 3K x 13 -5/8" 5K spacer spool (spacer spool needs to be same height as tubing spool). NU BOPE. Install and test 7" rams. 16. Pick up 7" dress -off assembly, 7" scrapper and all necessary BHA, slowly RIH to top of casing stub P Y� PP �'Y � Y P g while scrapping 10 -3/4" surface casing. Dress over the OD of 7" stub per guidance of Baker tool representative. Circulate hole clean with 75 °F 10.3 ppg CaC12. Use 3X pipe volume of surface casing to cut off depth. Temperature of CaC1 brine when mixed Is -- 75 ° F 17. POOH and lay down dress -off shoe and BHA 18. Prepare casing patch assembly as per Baker Tool Rep guidance. Pick up casing patch assembly and obtain all measurement as necessary. 19. TIH to approximately 30 ft above casing stub. Note pick up and slack -off weight. Proceed downhole gently while allowing patch to swallow 7" casing stub. Put slight torque on BHA as required allowing patch to get over the casing stub. Follow Baker Rep directions to ensure proper run and setting in the casing stub. 20. Slack -off sufficient weight to insure the casing patch is fully landed in place. Pick up on casing and pressure test patch against the RBP to 2500 psi, hold pressure and chart for 30 minutes. 21. ND BOPE and spacer spool. Hang off the 7" casing in new slips in wellhead. Cut excess casing. NU tubing spool. 22. Notify AOGCC 48 hours prior to BOPE test. NU BOPE. Install VPRs for 2 -3/8" — 3 -1/2" pipe. Pressure test BOPE to 250 psi and 5,000 psi. 23. Re- pressure test casing to 2,500 psi for 30 minutes against RBP. 24. RIH. Wash off sand from RBP. Retrieve RBP and POOH. 25. RIH with re- dressed TIW HM -1 retrievable packer on 2 -3/8" tubing as follows (NOTE: only change to completion is an additional 6' pup jt below packer; ensure packer has been redressed): 4 of 5 • • Item Length, ft Top Bottom Item _ 2 -3/8" 4.7# L80 8rd EUE 301 0 289 1 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 289 293 2 2 -3/8" Baker TE -5 SSSV 1 293 294 3 _ 2' Pup Jt, 2 -3/8" 4.7# 8rd EUE 2 294 296 4 2 -3/8" 4.7# L80 8rd EUE 9,402 296 9,698 5 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 9,698 9,702 6 2 -3/8" X Nipple (1.875" ID) 9 Cr 1 9,702 9,703 7 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 9,703 9,707 8 1 jt 2 -3/8" 4.7# L80 8rd EUE 33 9,707 9,740 9 6' Pup Jt, 2 -3/8" 4.7# 8rd EUE 6 9740 9,746 11 7" TIW HM -1 Retrievable Packer L80 7 9,746 9,753 12 6' Pup Jt, 2 -3/8" 4.7# 8rd EUE 6 9,753 9,759 13 3 Jt 2 -3/8" 4.7# L80 8rd EUE 99 9,759 9,858 14 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 9,858 9,862 15 2 -3/8" XN Nipple (1.791" ID) 9 Cr w /RHCP 1 9,862 9,863 16 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 9,863 9,867 17 3 -1/2" x 2 -3/8" TIW SBR Stabbed on @ 8 9,867 9,875 18 9,872' 26. PU landing joint and stab 3 -1/2" SBR onto 3 -1/2" tubing stub. Pull SBR off seat. Mix 5 gal EC1447 (corrosion inhibitor) and 5 gal EC6112A (biocide) in 20 bbls filtered CaCI fluid. Pump pill down tubing and under - displace 5 bbls from EOT. Stab SBR onto stub. 27. RIH SL. Prior to landing new tubing hanger, R1H and make 1.5" drift run to verify that SBR is stabbed onto tubing stub. RD SL. 28. Space out and make up and land new tubing hanger. 29. Drop bar (will seat in RHCP in XN- nipple). Pressure test tubing to 1,000 psi for 15 minutes. Continue to pressure up to 4,000 psi to set packer (follow TIW's setting instructions). Pressure test tubing to 4,000 psi for 30 minutes. 30. Set BPV. ND BOPE. NU WH. Pull BPV. Set two -way check. Test wellhead to 5,000 psi. Pull two - way check. 31. RU SL. RIH and pull bar and RHCP. RD SL. 32. PWOGL. Bola Adeyeye Operations Engineer 5 of 5 • • TO MA 05 -14 -13 ttiE I Gt' CURRENT & PROPSOSED Completion MGS C34 -26 KB: 35' Cook Inlet, Alaska ` Water Depth: 73' MSL Leg 1, Conductor 3 Tbg: 2-3/8" 4.7# L80 Ord EUE. Set: 05/8/13 API No.: 50- 733 - 2003 -00 Spud: 1968 / 4' Pup Jt, 2 -318" 4.7# LBO 8rd EUE @ 289' �I. 2-3/8" Baker TE5 SSSV @ 293' 2' Pup Jt, 2 -318" 4.7# L80 Brd EUE @ 294' 2-3/8" 4.7# L80 Brd EUE Surf Csg: 10 3/4", 40.5 Ib, J55. 4' Pup Jt, 2 -318" 4.7# LBO 8rd EUE @ 9698' Set @ 1732'. Cmt'd w! 1500 sx. 2-3/8" X Nipple (1.875" ID) 9 Cr @ 9702' 4' Pup Jl, 2-3/8" 4.7# LBO Brd EUE @ 9703' 1 Jt 2 -318" 4.7# L80 8rd EUE @ 9707' 6' Pup Jt 2 -318" 4.7# L80 8rd EUE @9740' 7" TIW HM -1 LBO Retrievable Pkr @ 9746' 6' Pup Jt 2-3/8" 4.7# L80 8rd EUE @9753' 3 Jt 2 -318" 4.7# L80 8rd EUE @ 9759' 4' Pup Jt, 2-3/8" 4.7# L80 8rd EUE @ 9858' 2-3/8" XN Nipple (1.791" ID) 9 Cr @ 9862' 4' Pup Jt, 2-3/8" 4.7# L80 Brd EUE @ 9863' Longstring 7", NBO BTC. Set @ 11,259'. B' 3-1/2" x 2-3/8" TIWSBR Stabbed on @ 9872' Cmt w! 1200 sx. TOC @7900' (swallow 3ft stub) 26#: Surface to 211' (Buttress Modified Thread) 01.06 MD TVD PORT PSC P5O 23#: 211' to 4711'. #1 2204 2050 12 942 1000 3804 3415 12 923 963 26# : 4711 - 8646'. #2 4845 4320 12 903 934 29# : 8646 — 11,259'. _ _ #4 5622 5000 12 885 908 863 886 r f #6 6779 60 12 642 864 #7 7357 6508 14 815 845 Tbg cut @ 9872' A #8 7932 7002 14 793 822 #9 8511 7495 14 770 799 U �� • #10 9121 8016 14 747 775 Uni-Packer VII @ 9880' �/ #11 9700 6519 14 Orifice GR 9919 -26' & 9932 -57' (SQZ'd) J GLM #9 Dummy @ 10278' HC -HD: 10247 -256 & 10,284 -305' XO Sliding Sleeve @ 10314' (Shut) Uni - Packer VII @ 10331' J � HD-HE: 10,355-65' GLM #10 Dummy @ 10428' XO Sliding Sleeve @ 10463' (Shut) HE - HF:10,397 - 453' ( SQZ'd) SS is Upside Down (1973) / Uni- Packer VII @ 10,481' ►Z � � � HI 10,526 GLM #11 Dummy @ 10610' HK-HN(u): 10,547-644' XO Sliding Sleeve @ 10644' (Shut) Uni- Packer VII @ 10662' ►� ■ 3-W X Nipple (2.813" ID) @ 10673' — — HK 10,690 �4 FISH: 2' HN - HR: 10,786 - 11000' ' 3 W Tbg w1 "Q" Nipple @ 11,024' (12 - 76) PBTD: 11024' • TD: 11282' �� / / /l. ACs C34-2(. PM I b6o1W Regg, James B (DOA From: Steiner, Joe [Joe_Steiner@xtoenergy.com) Sent: Friday, May 03, 2013 3:20 PM To: Regg, James B (DOA) Subject: FW: TEST Chart Mr. Regg, I was not here on the date of the test, but I have discussed this matter with the Toolpusher. The clock on the chart recorder is set for 96 minutes(1 minute per line). On the low pressure tests that were bumped back up — no visible fluid leak was found(possibly air). - As for the kill line test pressure drop it appears that someone possibly bumped the chart recorder, the pressure gauge stayed on 5000 psi and no leaks were visible. Part of the correspondence with the toolpusher is in below e-mail. Regards, Joe Steiner Drlg Supervisor XTO Energy Platform C 907-776-2534 My normal e-mail is out of order and this one is my back-up for now. From: Toolpusher [ma iIto: offshore@a Ila mericanoilfield.com] Sent: Friday, May 03, 2013 2:44 PM To: Steiner, Joe Subject: FW: TEST Chart From: Toolpusher [mailto:offshoreCa>allamericanoilfield.com] Sent: Thursday, May 02, 2013 1:08 PM To: 'Alaska_Drilling@xtoenergy.com' Subject: RE: TEST Chart Jim, looking over the test charts. I see that someone bumped the test chart on the 4900 to 4800 and the chart is set up on 96 mins time and the annular test is bumped up due to the Bag but no leaks . Thanks for keeping me on track . From: Alaska Drilling@xtoenergy.com [mailto:Alaska Drilling@xtoenergy.com] Sent: Thursday, May 02, 2013 12:25 PM To: offshore(a)allamericanoilfield.com Subject: Fw: TEST Chart Platform A 907-776-2500 Regg,. James B (DOA From: Regg, James B (DOA) Sent: Thursday, May 02, 2013 12:04 PM To: Alaska_Drilling@xtoenergy.comV l Subject: RE: TEST Chart Reviewed the charts. Please clarify: - What is time scale on your charts? It should be labeled. - Retest on the kill line does not appear to meet requirements of a 5000psi test; why was pressure decreased to 4800psi shortly after starting retest? - VBR and Annular tests are questionable — both re -pressured several times presumably to get a good test. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Brooks, Phoebe L (DOA) Sent: Thursday, May 02, 2013 11:22 AM To: Alaska Drilling(&xtoenergy.com Cc: Regg, James B (DOA) Subject: RE: TEST Chart Attached is a revised report for AAO XTOC 04-29-13 changing the CH Misc. fields to reflect 0 "NA" (as I did not see any remarks regarding a miscellaneous component being tested). Please update your copy or let me know if you disagree. Also, please include all email addresses listed on the BOP Test Report (Submit to: section) on future distributions. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 From: Regg, James B (DOA) Sent: Thursday, May 02, 2013 11:01 AM To: Brooks, Phoebe L (DOA) Subject: FW: TEST Chart Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Alaska Drilling@xtoenergy.com [mailto:Alaska Drilling@xtoenergy.coml Sent: Monday, April 29, 2013 6:49 AM To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay Subject: Fw: TEST Chart Here is the results from our last BOPE test on C34-26 Lonnie Drollinger Platform C 907-776-2534 ----- Forwarded by Alaska Drilling/KEN/CTOC on 04/29/2013 06:44 AM " Toolpusher" <offshore(rDallamericanoilfield.com> To Alaska Drilling/KEN/CTOC cc 04/29/2013 05:26 AM Ronnie Dalton All American Oilfield Toolpusher 828-447-5555 XTO Platform C 907-776-2535 offshore@allamericanoilfield.com Subject TEST Chart DOPE Test Charts — Rig XTOC MGS C34-26 (PTD 1680190) 4/29/2013 p4Zq 2013-04 7 BOP_XTOC_charts_MGS_C34-24.docx Page 1 of 3 10 i �` cr+kftl NG. Mc W-10000 ANY o 7,3= i ;,4000e-- v/ fie vd - 04'tA 2013-0<7 BOP_XTOC_charts_MGS_C34-24.docx Page 2 of 3 AM 5.10 *�1 b 3 1 �M ! _ Z` 00 f+ut Tcst � a H�rit Na "C Mp.�pQOC r. y ,} c J' ti 19 "WWA /C�� yap„ p''► � ,�- . .'� Wd 9 cA7-11 2013-6421BOP_XTOC_charts_MGS_C34-24.docx Page 3 of 3 14 CV ..per 14 • • {{ ( i SAN AA+ L G�Et1 OR ALASKA. OIL AND GAS 333 W. 7yhAVEi4UE.SWATI, 100 CONSERVATION COMMISSION AtctioRAGE AtA MORE (NM P9-14133 FAX (M7y 2767042 Maria Perez Regulatory Analyst atettago XTO Energy, Inc. 200 N. Loraine, Suite 800 SEP a 4 dllz Midland, TX 79701 Re: Middle Ground Shoal Field, E, F, & G Oil Pool, MGS #C34 -26 Sundry Number: 312 -320 Dear Ms. Perez: 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, 0 10 ,4 42.1° Daniel T, Scamount, Jr. Commissioner DATED this ' ?day of August, 2012. End. • • d ri f T0 ENERGY a subsidiary of ExxonMobil RECEIVED August 10.2012 A 1.17.; i 7 2012 Masks Oft L and Gas Conservation Commission J� ' i r Ana: John Norma, Commissioner 333 W. 1 Ave., Suite 100 Ate, Alaska 99501-3539 Rt; Paean 10.403, request for smithy approval Objcct v' a; Pull tog, replace wellhead, Lad nm new gas lift string. Middle grand Shoal MC34 -26 Production Well Middle Crowd Shoal Field, $, F, ,R Cc Oil Pool Cook inlet, Alaska M150433-200934000 oergy Inc. hereby submits its Application for Sundry Approval to poll Mg, seplaro wfead, and run ps lilt sa iuR. Ondosed ass the 0)11ov/ft auachinenes: I. Form 10403 Application for Sundry Appeo vaL 2. Cover Page 3. Summery Page_ 4. P1+24001011 Plot 5. Sub Surrece Soy valve Repoli 6, Deviation Survey. 7. Job Procedure. I. Current Wellborn Disgrace. 9. Proposed 'Wefbe a Diagram. 10. Current Wellhead Subatomic 11, Replacement Wellhead., 12.. SOP Mande. If you required additional information. please c000tact Paul Fieel, Engiaeerbss Manager at ABC 432420 - 6749. Sincerely, Marls L Perez, Regulatory Analyst Tel. l+ie. A1C 432.620.4323 Copy tat: Pant Pigei. Engineering Manager 200 N. LORAINE, SUITE 800, Md1LA1s'D, TEXAS 79701 • • STATE OF ALASKA ALASKA Ott. AND GAS CONSERVATION COMMRSSMON . ` APPLICATION FOR SUNDRY APPROVALS 20 AAC20 22o I. 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Olis - •aaca and SSW NO 00 end ND 00c Sae Alladaipl 12..Mudwdodr, Demaiseran Summary of Pncppaal in 13. We Cfaes a1Nr mowed wort' O.nep Opa.aoms Program ❑+ NOR Skotab R9 Fapi.aoray ❑ D.eMopnn.etl El Saelo. 0 14.6itewlad Dale Nov 2012 10. Nil Stales , propaeaewan CeamenKlnp Oporotionsi ®ti f1 Ws 0 WUSPL 0 id.0 19. voitolAsrore: moo: - - law ❑ um 0 'ma [] Abandons CorenMidon Reperrafla.: _ c3snaa 0 swum 17, I. Nonlrr ohlify Pef the be r skip is Iris and ivomod ea IM. but of my Useeledgo eonbt! Paid Fkgel, Inpr 4=41211-11743 Pthded Nom Moro Pens 1100 Rat7dnsfy Mann Sliundua Pions 4324204325 Dabs - - O!16I2012 -i., .. . , .. a ir COMMISSION ME ONL.7 Coed doom of unnotal: Notify Commission so the a raprem daftea army army inks I Nreaee. 3 Plug Wooly 0 SOPTos '0 fAschankid Meagrily Tart 0 t,madon Eipraarae ❑ Oder' Subsumed Fans Raqusad: 1 , : ! - �' ' 4 /4-.... f .- At�IOVEfl BY oared to= Cf]Mt1NiSSl(kIER THE CO MMMISSION Doke Sta9b2.- Force 10403 RBeA1a1 112010 DUPU C p Subsea kr buFolcate • • • • Form 10-403 Packers and SSSV MD (ft) and TVD (ft) MD TVD SSV 290 290 Pkr.1 9880 8680 Pkr 2 10331 9079 Pkr 3 10481 9213 Pkr 4 10662 9374 S • E NERGY August 15, 2012 To John Norman Guy Schwarz Victoria Ferguson Cc: Scott Griffith Scott Landon From: Paul Figel Subject; Workover for MOS C34-26 (168 -019): Return Shut -in Well to Production. Objective: The objective for the walkover proposed for the C3.3 -26, located on Platform C, Cook Inlet is to rcplac c the current 3 -1.'2 gas lift String with 2-1/8" tubing and return he well ;o production. The well currently has 4 Guiberson retrievable packers fiat were installed in 1973 to isolate the venous zones. Past experience has shown that these Guiberson packers require milling out us they will not re/ease. Therefore, for economic purposes, the 3 -t!2" tubing will be cut above the existing top packer and will be conjoined with a PBR below a new packer, This well is currently equipped with an outdated product (Type D Utei- Compact Head) that Cameron no longer supports new has adapter parts to allow for a new tubing hanger to be installed. Therefore, the entire existing wellhead will be removed and replaced with a conventional mule- compartment wellhead. This will be done as milled in the procedure requiring that the 7" Longstring be cut below the deck to allow the removal of the lowermost casing heed section. Approximately 150 of he 7" casing will be replaced and brought back to surface and hung off in a new casing head with slips. This will allow a new tubing spool to be installed, Well History: This well was drilled in the East Flank in 1968 and completed in the 13 separate Hemlock intervals from the OR to la. The well IP'd 1970 BO1'D, 24 BW & 689 MCP.. The C34-26 was offset to injectors C -Line (4000 BWIPD) and C23-26 (3500 BWIPD) as of 1969, A production log was rut in July 1971 as the water jumped from 125 to 500 BWP13 and oil fell 1500 to 800 B)PD. The survey showed 8 of the 13 intervals contributed less than 50 BPD. Therefore, in Dec 1971 an acid job was pumped which, according to the 1972 production log, bad minor inflow effects but vetifled that the ITE -HHF, Ill -HI( & HK -FIN were contributing +90% of the water, The well was tecompleted in 1973 with 4 isolation packers and sliding sleeves to selectively produce: 1: OR-IdD (open), 2: HD -I-fF (closed), 3: HI -HN(u) (open),. 4: 111 -HN(1) (open), .& 5; FIN-HR (open), however, the sliding sleeve for the 1-1D -IIF was installed upside down was closed when thought to be open from 1973 -`76. This was discovered in 1976 when slickline tried to "close' the SS but actually opened the sleeve causing the well to kick and flowed 1600 BPD (a 1700 psi WHP. The top 3 SS were closed 41 MR-HD), #2 (Hl -HF) and #3 (}11- HN(u)) and the • • 2 well tested 152 BQPD & 102 BWPD from ► the HX-HN(1) & HN -HR. In Dec 1 76, ire zones were =perforated and gained 60 BOPD without any water. The C34-26 lost the injection support of the C -line well in 1981, 5000 to 1800 BW1PD. and then again in 1984 when the C23 -26 had the HC -11N cement squeezed dropping support to 300 BWIPD. Sec attached Production Plot. The last treatment was done in 1985 with a small 2000 gal xylcne-acid job performed with coil tubing which had minimal effects. The well was shut-in in 1988 due to economics only mailing 9 BOPD & 81 BWPD. The cumulative production is 3.3MBO. The meted date for operations start up Is November 2012„ Please contact me at 432 -620- 6743 with any questions or concerns. Sinccmly, t Paul Figel Engineering Manager • WORKOVER SUMMARY for C34-26 Same of work Cut the 34/2" production tbg below the top Ming sleeve @ 9841'. POOH with the current 3-112" as lift string and replace with a 2-318" gas lift string that will stab onto the tbg stub (4 0846' with a PBR assembly. The current lowantost casing heed section will be reps with a new conventional casing head that will allow for the install iian cite new tubing spool and tubing hanger. Csirreot:Well Status: Shut -in 1988. Last prod was 9 BO 3t 81 BW. Sl AVM 500 psi. Well bah: See Attached Procedure & TVD Survey. SSSV test r see attachment. MEE Pnod is 90% Water Cut based on last prod @ 9 BO & 81 BW. 8.4 ppg FiW = 0.437 psi/ft 34 API = 0.3702 psi/ft. Mid Perf TYE% 9192' Top PertTVO: 8715' BHP 'a ((0.1)(0.3702 psL1ft)(9192') +(0.9)(0.437 psitftX91921) + Soo psi =' 4455 psi Pbyd = (0.1)(0.3702 psiIftX8715') - (0.9X0A37 psi/ft)(8715') a 3751 psi MASP • 4455 — 3751 = 704 psi dill Weil 4455 psi — (0.052) (8715' Top Perf TVDD) (x, ppg) x r 9.8 ppg + 0.5 ppg =10 3 ppg rued Mud Recipe will be 8.4 ppg P1W + /12 lbelbbl CaC12 mama • NA as a producer aOP Ram Confirmation VP11. for 2-3/r to 3- 112". Schematic Attached. liii+erkuv+er >1ic- XTO derrick is a permanent rig on Platfomi C. Contact: ludo: • Operations Engineer: Paul Figel, XTO Energy, 432 - 6204743, uul 6 l . mu • Superintendent: Scott Griffith, XTO Energy, 907776 -2506, scout th clamant .com Aj(x 18«0 4 _MIXLEGRUO — - -- - — - i '81 Offset IN C-Lina SI 6000 = 1 73 lisped +SetboPlvs I (SS HOME Closed) , 1 '- \ S 1, 1000 4 84 Offset fn) C23.2$ 8QZ HC -NN +1Set ISO Piz • ' 'I li, _ I 1 1 1, 1 t ,1 I 1 1 I ./ 1 : , 16 t r A- ‘ 4 i im _ . i ! 1 i ii ., i Y i . .,) #\,11 , .., ,.... it ,,,,_ , , iiii re ve 10 s na� - . trim pc3420.wins 01.1h rPUP I aka! .; oo • CO Air 5 - --- CD GA 0)> T 9:11 Al�u Ti �APDfde�e - -�— , A Tel 1AXPO Alas, 1 — T — .'.-.. TrrrP' 1 !.. .r • • Is .I .. .. .1 ■r,- ---- n .. 1 i or .,--r• . -in i .r'r , -lr .. .n , • u 9 . .. "4- 86 ,...,$ , h o ' , .. '$ 1 88 78 71 72 73 74 75 78 77 78 78 80 81 92 B3 84 1 85 Of p86 W DO 338014 r.r-,r Alesiai 011 and Gas Canserratian Commfsalon Safety Ve va System Test Report Operator XTO Energy Submilted By: Battey Phillips Dale: 3120/2012 Operator Rep: Barnet Phillips Fleidi i:itIPed: MCS XTO C Flairano AOGCC Rep: Man Here Separator psi: 1.1'S 6Sr6S LIPS Well Dem Pilo is SSV SST! Retest/S1 Date Well Type Well Pressures Gas Lit Waver Well Penult Separ Sat Tat Test 'Teat Date Passed Retest tnt,w+s[1•[sra Inner Outer T Tubing Yes/No YeLNo Number 1 Number PSI PSI Cade Cede Code Or Date Shut hi G AB. c Mu, 51 PSI PSI PSI _ Cl 2-23 1900200 6$ 37 RUM& P P OIL 100 Yts !+o C13-13 t 1022130 N � L'112o06 Si No -- No 013.23 1 880990 68 37 WM P P OII, 95 Yes 14n C III I 3A-23 1901060 i P lirja OIL 90 Yea No C21-23 11190870 P OIL 95 Yea No C21 -26 11190040 P OIL 100 yes No C2111-2.3 1910440 MI P P OIL.. IMINIE Yo No C22.23 1880160, NM MIS 12119/2004 SI - Yes No C22.26RD 1760690 SI Yes No C22A -36Ll 2041170 OIL M 85 Yes Nn r C24 -26310 1790620 MI 41111992 SI Yes No � C31•22RD 2041400 IIM OIL _ 90 _ Yes No C32 -73LW 2020340 OIL 75 Yes No C34-26 1680190 1111119U SI _ Yes No C42 -23 !780240 OIL 95 Yes No C4T•14 1811320 P -- OIL 3425 No No Welly 11 t'tuigronrn[s: 24 Failure 0 Failure Raw 0.00% Elemt Reims rte • 1131 01/2011 Pulp f of I SYS MOS C P:atfurnt 5•20- 12.xii • • + ' .. istiC +1.,... .mbos- , C P12152rm W19 01-20 t I ... _ N'l EQ I klis141 SUM Plana 1 Coardigalaa 6leee ,_ Make AzameUt Two x Y 11 -5 1 E t all! me ` = viii iric X00 it 11 71*1r 0100 0:04 1001 0.00 .140400 38411 Z# '3240 1110_[ 0.031 500, 404 1 75.00 0 • �.X 7800 4000 211364 79 241423244 -0.05 -0103 031 Al 2 100.00 0.171 311,00 100.00 -ail 231384.782474232.45 .004 405 082 - 0,05 8 125.0$ 025 3.00 129`00 2000 2333 772474232582 0.03 •005 t.1? a 4 I tel 0 . 121 00 15100 4500 231354.62 247+ 12.57 0.09 4151 0188 �a... 5 1 175.00 0.17 46 CO 115,00 70.001 231364.86 2474232.81 0.13 0303 - _ 136 0.01 6 200,00 0.17. 41.00 20000 9500123126491.2#77423267 0.15 005 4.05 -Q.fl2• 7 225.00 1 2100 22100 120.00 231354.94J2,4T423371 025. _ 0 0,20 -0.04 8_ t 250.001 - O.Q81 3 1190 250.00 145.00 231384.83 247423274 4.11 Q.33� _ 0 27500 4.25 ., 303 001 276.10 170.00 231364.88 2474232.7 au ° 41,`G2 - 0.1s3 ate JO VG-001 0.33 " 259 01 300.90 135.00 2,11 77 2474232.01 032 4.08 1.021 018 11 221001 0.42 1$ 32 450 2"2 0.00 '23/36454,2474232.73 014 0.10 1 - 74 - ¢25 17 X00 0.42 230.101 134'00 24300 23138451 247423.130 0.11 43'1 0,35. 033 1lnln _ 383 00. 0,33 241,001 383100 25100; 23136444 247423210 0.08 - 0.38 1.131 . - 012 t 401001 0.75 13.00 40171.00 29500 231364.44 2474232.74 024 2.0 2.73 430 2 500.00 3.60 56.00 49992 39413 51387.52 247423451 2.09 27 -- 1. • • -1-98 3 800.4701 - 5.25 88.00 63983 494 es 231374.411 247423591 31.65 10.01 3.30 -2 16 4 700.03, 7. 131,41'0 86®.11 594.11 231383.00 247421202 403 11116 4.3 251 5 50006; 7.25 154.110 105.311 393 35 231391.14 2474 7'15 -4.701 3115 ..._.,, 244 1144 8 900.001 1050 17410 89717 762_17 231301.62 2474207.38 44.441 3017 4.94 2856 - 7 1015,001 14.75` 174:00 844,73; 02 73 231336.3112474185.58 48.1411 3253 425 5040 8 1101410r 18.001 175.90 160. 8681 161.86231308.35= 2474157 47 -1424' 35.2 528 _ _ . 78 as 0 1200.0111 22110 15200 118481 107861 331401.55 2474123„35 40330` 39x,21 1 11189 10 1300.001 28.00' 17600 1275.95 1170.95 � 231403.17 2174082.77 4 . 1 41.75 4.001 1513.29 11 1400.00 30.30 970 13640 1250.112 23140623 2474025 55 - 196.95 4158 4.80 202.53 12 150800 32.00 144460 1344.80 241410.00' 2473298343 •24 . z I 55.882 1.50 262.34 13 1601-001 3240 - 1 7 /i76 .- 7.31 1429.31 231414.37' 2473041.00 40023 9140 0:061 30523 14 1704.00 31. 174.00 161023 151433 23141509 217387637 -35283 81.92 0,25 358.05 t5 1500.00 3050 174.03 170483 162193 23142293 247382336 -401.21 or 22 1.28 40330 18 1900,00 30.50 ° 172 1761.00 168800 231427:38 2473778. - 7363 1.02 00.43 17 200000( 31501 113.33 187571 171171 23143352. 405 NI 80.72 ' 1,12 51183 • 13 2100.05 3125' 173.00 198200 185709 23143363 2473873 7.. 557.572 86.57 0.25 641106 19 2200.00 32.001 17200 ; r .24 1941224 231444.3512473021.23 0341 • 818+41 20 230100. 321110• 17000 21 " .05 231451.44 2473568.73 .881.13 101:70 196 86093 21 240010 32.25 17200 2216.74 2111.74.231468.56 714.15 11102 1.04 12255 23 2610 ■•• - NW 172 W 2301 4198,5E 231484.85 1247344_3! 787.301 17.50 150 778.28 23 2605.00 32201 171-00 2334,831 227183 23471.86 2473406.48 - r121.10, 125'.!8 , -. - 530-831 24 2100.00 34:00L 171.0 2487.97' 4382..37 247338340 827 1342? 0.60 008-41 25 280000 $4. 1 173.00 2550.03 ` 244553 23145616 847329737 .931.041 1422551 _ 075 042.72 20 280000 3228 17300 2434.14 2529.14' 231 .12 2473242.88 , B.47i 1437$1 _ 2 '', , 7'$ 27 3000.00 29.75 153.00 '27131.10 2314.90 231 3 413141.65 - 103717 151.73 t 5.72 I. T- , Tie-in 3131.00 25.75 163, 2535115' 273016 23109 70 23.25 179.0000 295490! 284900 231486 70 24730134; - 4102.71 , 15050, 123 1168.64' 15048, 0.5 115 2 424.00 320.25 177.00 3289 47I 228401232148073 2 -12 r _ t53 1 0.91 WSW 3 3510.00 31.25 1 77.00 3223. 3116.61 231402.10 247',810412 i 157.401 0.64 1312.87 4 3731.00 30.23 778.00' 3353.3 1 , 3248 311231493 72 2472828.11' .14112.281 180.84 014 1381.13 5 1888.00 3023 17600 3485931 33 .0123149483 2472747.85' - 1431.31 18350- 000 14118.38 0 4111 34901 170:00 383_57_522 7. zn406.O5 2473838.10 - 1591.03 10754 011 1580;89 7 42004.07' 30.E 116 3 '18T '36156'331407.85 2472588.13' .1840.54 170 401 1 .53 132725 i 8 1 4424,00 22.60 17700 186233 3847.33 21150102 247247888: - .1758241 178.07 0.57 1735,57 0 457900 29 25 17800 406710 3902.40 231501.61 247240287 - 182020 151 301 0.96 181147 10 4787.00 2075 17000 4278,01 95 2472295 -98 - 1631.85 184 04 151575 11 501100 2125 16110 4470.63' 438153 28150x.62 247210253 4036.33 184.17 0.40 2021.03 12 3112.01 1200_ 1 /300 4555,_ ` 4450.50.231501.02 2472157.38 X196 112.5$ 206528 13 5204.60 27.75 164.00 4834.;2 2314495 2 7472104 50 212448 179.37 0.1 2100.27 14 5328.00 2900 161.00 4745..83 484153 221402.8* 247204172 - 215334 11,44' 153' 216117 I • • Merund m41 . Iq •r: ,. r 1 N t.B 6°ov Daplii 0110 It it 1 „� [ 10 ' ,�- R It tN�MaO R 6.- 15 04!1,05 17 3000 10300 4817.81 471W 23145015i 20111114.22 -T22416 176,00 1.511 ..- ,02 as . ^' 47'5 152.00 :. 06 4081.1 n11�d3. ?Qi 24'71901.51 2320.71 171.76; 0:6' 2306.$4 17 5712.00 25,15 155.00 5140.53 t 231478.5412471 ..7. , ±4497.02 1556$ 1.001 - - 10 5762.561 26,26 155,00 528.42 5141421231405,112 , . 7D 1 .6 0.9i 18 ' 413500 7.1.50 141.00 4141378 534486'231454.44 2411665.32 02574.811 140,2f 1.021 j&IDA + 20 6294J.001 29.75 157.00 569057 -'T 47" 231445.24 2411570,910 X 46 1.031 156 1.22 .r, WO .< . 00 75 114.001 5026.5 ' 53244t 231441.84'247155643 IA 256Ct00 1 8511,00' Mt I 162.001 577610 . 5073.10 23142515 24714472.91 •2757.50 .09 1.17' 2744.919 AX) MIL 191.001 5584.02 6 Po -w 251411.52 2471412 4917.78 1 , , • 0.41 2505.50 • 24 6761.00, 30.50' 1594* 5L20.25 561525 A•1 . 2471176.44 87.10 ..rat 2554 25 . _ 7 90:75 1 6800 51 ,55 6023.6 231344$$ 2y47127 .29 X04 97 , • 02131 ._. 2847.95 25 716x190 30.20 1 Y 8294.12, 6184.12 23136464.247117623 -3064. K 003 3014:98 27 720400 3035 1110.00 0375.9k 5270.88 1341.91 2471130 45 3101. _ 6718 2 , 26 7283100 30.00 189.00 6420, 0323.02 231344.54 t1 .555 - 3131.65 'T 693 2 2 1296.05' 3176 167:00 845527 035037 2 34201 2471053,00 •9147.17 44,73 , X06 313412 0 30 7424:0 315D 154 4, - 2.7- 548052 231 • 2471020.95, .3212.03 42.54 1,211 - 5203.27 31 757900 30.00 117.00 8=42 411414.42 231925,00 2117 112.44 -moue 5500 1.07: 328116 . 32 7713.00 ., 3140 107. , 4 865194 6752.01 231311.55 247095044 3362.45, 23,8/ 0.54 3374,50 33 768700 21.50 107. c i 7049.44 606446 23129478 2470736 15 -3407.x3 9. 63 0.721., 3460.80 1 34 1 80870000 s 31.25 1 „ II . , 7012.78 23128441 4713194.29 , }439-06_ 4.09 0472 x.05 35 8214.00 31.30g i61. • . 72:43.27 7136.27123127![38 247081808` 3814.77 4.22 029° 340425 1 38 8288.00• 3226E 189,60 7299.13 7114 231271x26 247=83, _ _ 404794 .11.88 1 9534. • • 17 1 0393, 3236' 159.001 73... . 7269.64 217052520 •3'708.!21 - 22.12 OOO ' 370.i. 38 .. 31,5Q' 191.00. 701224( 231,48 347031 * -3841.94 •46.x 1181 3837-X1 30 5660.00 30.75 1 1.001 7906:.90} 7704 25i2o6.43 _2470270,21 .15 68:33, 0 . 3956, 40 903300 ,_ 3025 194.001 7941.62! _253117.93 2470200 4031.64 -96.13 1,06 403946 l 9 6517 1200 75, 1 .091 044 .4:4 231154.86 2470116 - 4117405010551 I 1442 411 • 'llV 9324 00 30.90 19 .WS 1112431 667.43 10 1111 2470057 - 47/11.501 - 110.60. 1.46 4477.'5 43 51430,01?; 2973 194,61 53 619x0 231136 24700021 47 3. 133.+4$ 1.18 404.37 44 45 m R_ 2 . 0 ' 1 1 0 ' . 90[2510 .5 ( a t �4 5591 es 8475 55. 5181. 245566217 35462 92 886 4350. 47 9870.5 26.2$ 16100 563524 1331.24 23107023 24$053.67 .4412`05 - 100.25 441616 48 10024.00 28.25 18600 8606.77 '570372 23103044 315673400 X10.53, 4131.191 140 4,35 4$ 1 .00 2040 487. 1670.15 17 231005. 2469706.68 .4532,,74 - 2005:06 1,27 463.93 50 102N,� 20.00 157,6 . _ T . 0999.09 231046 47 tr ' -. 4003.51 414. 057 480827 81 1037200 ,233 167:00 9112.39 '11030 231030:90 249115176.11 .4452.72 - 22142 0,66' 4607.82 62 1031000 110, - 9244.12 9139.121 'I6 4 1012. 47231.53 -23142, 127 4731 53 10647.04} . 5 151.00 038007 ' 2 310/435 244 - 4794.55 X41.70 1.341 4790.63 54" 28.23. 86.09 02 _. 19x0 940�0p 002.13 +1 94 8.52 ` 4 i. ' 3740.47.x1 SS 1062100 61.7160-00 960484 8409.54'230965.45'3459321.13 •4915.11. 487.541 2:32` 407524 56 11015.00, 33,00 164110• 687041, 5574.01 230914 50!24149275.481 - 4964.701 277.471 2791 4172.35 00 51 11173 26.70 $07001 991470 0700 6 1150 82422469190.74 •0043.916 266351 ta 5052.42 8d , 1 I 3125 189.001 9905`7 99011:57 231 }.09IZ40514 05' - 5066.00 3155511 1.011 5104;1^4 2 • • If XTO ENERGY INC. WIGS C34-26 COOK INLET, ALASKA -- EAST FLANK Return Well to Production Procedure WELL DATA: SURFACE CASING: 10 -'Y." 40.50 155 BTC. Set ( 1 ?n2'. Cot wf 1550 sic. LONGSTRING CASING: T' 23, 26 R 294 N80. Set @ 11,259'. CSm w! 1200 ak, ?HOC { 7900' Surface — 4711': 23W 4711 — 8646': 260 8646 — 1159': 290 TUBING: 3 -W' 9.30 MOW SUE @ 10,683'. PACKERS: 4 ea 7" Gu b erson Uni•Packer VII @ 9880', 1 31 ,, 10,481' & I0,662'. Ras set in 1973. PERFORATIONS: GRAM 9919 — 26' A 9932 - 57' HC-HD: 10,247 56' & 10,284 —305' HD-HE: 10,355 — 65' 1.1E41 F: 10,397 —453' Ha 1UC: 10,526 — 40' HK -11N: 10,547 -644' & 10,690— 752' FIN -14R: 10,786 -- 11,000' FISH: 2' 3 - 112" 11ig wI 1 Nipple ®a 1 1,024' PUl D: 11,024 BEST: ] 70 Deg F BHP t 450 psi (SI WMMP' • 500 psi) SMALLEST ID: 2.813" ID X Nipple @ 10,673' PRESENT STATUS: Si wt 500 psi W HP & 350 psi Cu Press, OBJICTIVE: Replies !1"' GL strbg w12.318". • AFE 81200M5 • Prior to Workover, Siteldine will run gauge ring to delerealo a the eendlel . of the $bg ID for WL jet cat* If tbg is scaled up, Coil 1hg win be need to eleain ant the tag ID. • The entire D Compact Wellhead will be replaced whkh will require euttlai & replacing the top 150' err' casing. • Need 11" a 13418" clamp adapter for BOP. S -14-12 VAPI.Paieksilonseeduseim3.40C34411RWIPPriettlavt 11-14 -112no • • 2 Emolument: • RRCP Plug (Pollard) Installed in 2-3/V XN. • +F' drop bar w/ ball (Pollard) Materials w • 5 11 l WC I447WR Corrosion Inhibitor (Nalco) • 5 gal 13C6112A Biome (Nalco) • 100 bbl Gil Pill p#/bbl F1awact + 3 gal Cteencide) (Provided by MI) • 67,000 lbs CaCi (112 lbsbbbi l 1W to build 103 ppg) Maintain MW from last wen. 8-14-12 via' -4 s Wrr ['meagre a.t4rt.doe • • 3 !RPC1 t)URE: 1. Bleed-off well to header. 2, RU Slickline & lubricator. RIH w.i' 2.70" gauge ring to X nipple @ 10,673'. Reduce gauge OD if the 2.70" will not get DH, R!H w' pulling tool to OLM #8 @ 9835+. Latch & POOH the dummy valve, RI) lubricator. 3. MIRU Derrick. Mix up 400 bbl 10,3 ppg CaC12 mud (use from last WO).. Ciro to kill well through GLM #8 (4 9835'. Take w IIivre fluids to disposal well and recover /maintain the 10 -3 ppg Salt mud. 4. SD & monitor well for 60 minutes to make stun well is dead. 5. Notify the AOGCC 48 hrs prior to SOP test Set BPV, ND WH. Set 11" 5K x 33-5/8" clamp adgptca. N riser & SOP's. Pull RPV's & set 2 -way check valve. Press tee BOP's to 25U_psi 5000 psi.. Send I) Compact WH to OS for scraps - -- 6. MI 11,400' 3 -112" 15.5# S135 drill pipe & 6 eat 4-3/4" DC`s. 7. M1RU Pollard WL R11.1 wl Radial. Torch cutter & CCL. Cut the tbg ti' below the SS @ 9841'. POOH. Observe the quality vista cut tbg as per Step t€2l if stub will require a dressing. Leave WL on board for Step #17. 8, RU slips & tongs for 3 -112" sig. POOH & LD 3-1/2" tbg w18 GLM's while checking for NORM. Send tbg & 01,M's to onshore to be sold for scrap. CasinE Cut for Cs2 Spool Removal: 9. MI 41ts 7" 29# L80 STC. 10, RBI wt HOWCO r 23# RI3P & set (eat 500'. Close pipe rams & press test to 1 000 psi. POOH. Drop 500 lbs (20') of sand on top of RBP. 11. MU 7" casing cutter on DP. RII•I & cut the 7" csg s20' below the WH assembly. Circ out any gas. POOH & LD cutter. 12. NI) HOP's. 13. Remove the bottom clamp from battarn of D Compact WH. LD WH wI casing hanger & the 20' 7" casing stub. 14. NU new Cameron clomp x flange casing head. 15. NG BOP. 16. Press test the new clamp against the RBP to 3000 psi for 30 min. 8-14 -12 V . P4rul8. kaf o rde- 14461(3446awrRPreteen1-1413 -+k+c • • 4 17. RIH w/ 5 -3/4" ITCO Spear wit 2.0" ID and engage the top of 7" & PU 50004 over string wt. RU Pollard WL. R11-i wi string shot & CCL. Apply recommended torque to 7", Fire string shot in collar between 100 -150'. Backoff casing at collar. POOH & LD *3 jts csg. 18. RU Casing Crew. MU Triple Connector screw -in sub to 7" Csg. WI new 7" Csg & screw into collar. Screw on 7" swage wi 1502 2" connection. RU mud pump and press test the 7" connection against the RBP to 2000 psi for 30 min. Bleed-off press. RD I30P's. Hang off 7" on slips in Wit matte out and install new Cameron Tubing Spool. 19. Notify the AOGCC 48 hrs prior to BOP trot. NU 1301 Set WH testpluuin ibg spool. Press test E30 P' a to 250 psi & 5000 psi. 20. RIB and wash off sand & retrieve the 7" RBP ® 500'. 21. Based upon results from Stop 47 -RIB wf c -off mill to dress off top of the 3-1/2" tbg stub @ +9846`, BHA to consist of mill, casing scraper for 294 & MAOTRAP. LIGHTLY tag up on tbg stub }d 9846'. Dress-off tbg stub as per instructed. Reverse erne 20 bbl gel sweep. Make sr cuing scraper run as minimum if tbg stub dress-off is not necessary, 22. RII3 wi Howe° 7" RTTS packer to 9735'. CCL has collars @ 9719' & 9763'. Est cue w1 PIW, Set pits. Perform MIT or 7'" x DP annulus to 2000 Monitor press for 30 min.. POOH & LD DP. 23. MI 10,200' 2 -3111 4,70 L80 8rd EEE tbg (iacl 3% excess). 24. RIH wi TIW 7" HM -1 Retrievable Packer on 2 -318" 4.7# L80 8rd EUE tbg and land as follows: ''item Length, ft Top Bottom 2-3/8" 4,7* L80 Bed EUE 300 0 . 300 4' P Jt, 2 -318' 4.7* 8rd EUE 4 300 304 2-318" Baker TES SSSV 1 304 305 4' Pup Jt. 2 41* 8rd EUE 4 305 309 2 -318" 4.7* L80 Brd EUE 9,386 309 0.605 4' Pup. it, 2-318" 4.7* 8rd EUE 4 9,695 9,899 2 -3188" X Nipple (1.875" ID) 9 Cr 1 9,699 9,700 4' Pup .it, 2-318° 41* 8rd EUE 4 9,70} 9.70+4 1 Jt 2-3/8" 4.7# L80 8rd 1811E 31 9,704 9,735 7' T1W HM-1 Retrievable Pec er L80 4 9,735 9,739 3 Jt 2-3/8" 4.7# L80 8rd EUE 93 9.739 9,832 4' Pup JL 24/8" 4.7* Sal EUE 4 9,832 9,836 2- 318" XN N apple (1.791'109 9 Cr 1 9,836 9,837 4' Pup Jt, 2- 318' 4.7 #8rd EUE 3 9,837 9,840 3 -112" x 2 -3JW TZW SBR Stabbed on © 9848' 6 9,840 9,846 8- 14-12 Y>>8 tkwaakriProc&∎itflial44 k14.26RWT,'PrIxdu,s • • $ Gas Lilt Design GUI MD T110 PORT PSC PSO #1 r 2050 MEM 942 111111 ► T 02 ilEVAI 3400 MIMI 023 , a3 4300 12 903 934 94 5821 5000 12 MILAIN 1 0192 'Ai 12 13!!16 MILAIN 5763 000o 842 Wail 87 7348 6500 EE 815 MUM OEM 7930 7000 =MN 793 822 8517 7500 MK= 770 799 010 91,1 8000 775 011 907? ,, + 14 teeth UM to bases 4' Pap sit on top & 6' Pupil on bottoms. 25. PU laaadingjt dt stab 3 - 112" SBR onto 3 -112" tbg stab at 9846`. 2aft. Pull SBR offsets., Mix up 20 bbl biocide/pm fluid pens to contain 5 gal Nalco WCI417WR + 5 gal EC 112A in 20 bbl FIW. Cite pill down tbg w1 FIW. Under pill by 10 bbl inside the tbg. Set down SBR. 27. Space out & make up and land new Tbg Hanger. Run in lock screws to energize hanger seal. 28. RU Slick line & press test lubtleator to 4000 psi. R11I vv/ l S" tool to 8200' to verify the SBR is stabbed onto 3-112" tbg sub ® 9846'. 29 . R T H w 1 MN p l u g d t set i n X'd' nipple @ 9836'. F r e e s t e s t to 1,000 psi for 15 min. Monitor (shaft Cont to press up to -13,500 psi to set pkr. Hold 4,000 psi on the tbg for 15 min. POOH w1 SL. 30. Set BPV. ND BOP's. NU WH w1 new tbg head adapter. Pull BPV. Set 2- way ey ci . Ted WH to 5.0110 psi. Pull 2 -way check. 3 L RU SL. RIFT & pall the PXN plug. RD SL PWO gas lift.. Paul Pigel Engineering Manager 844-12 Y r.willwa a 34-29C34.xaerivtT Procaine 244 e • • 41 WELL Si 1968 I LF 3 -s1.12 ENERGY pwa� Present Completion MGS C34-26 i ' r KS: 3 Cook Inlet, Alaska , • Water Depth: 73` MSL Leg 1, Conductor 3 API No.; 50433 - 2003.00 Spud: 1988 lbh: 3-112 ", 9.3 #, N80, EUE 8nd @ 10.883' Set 4 -1543 R St: rf Cog: 10 3f4 ", 40.5 lb, 355. OU0111111V 2 SO 0 1732, Crttt d vet 1500 6x G GI�A #t 2141 A9.L Cs1.1A MY e GL1'A #2 4x21' AR° DUML# C wt' GAS LIFT G #4 6 x'116' VALVES GLhd 7855' GLM AQ b 7bli iil.itt � � 1' GLM n8 9833 Ms ICI Nipple t0873' Longsleig T. N80 8TC. Set @ '11,259 , 1 COT t0B83' Celt wi 1200 ex TOC 37900' 23# : Surffc810 4711'. 22:8!! : 4711- 8846•. 29# : 8648-11,25W. . • M t 'X0 " Sliding Sleeve 11341' '•• is Um-Packer VI! 9890 - � � GR-GS: 5919-26' & 9932 ..57' t.: :1 •R■ >" HC-1 10,247 -256' & 10,284 -305' GLM #9 Darrry 10278 x 9€O" siding & eeva 10314' ' 1 � l' "' Uni•PacxerVU 10331' r;• RD-HE 10,355455' SS 10,483' is Upside down iiriti HE -HF: 10,397-453' GLM 10 Durnrny 10428 am 74C7 S'.iing Sleeve 10483' p�� i`� : —i'. trh4Parl ar VIE 10481' i * '- HI -HK 10,1120 -640' 1115 HK - HNCu): 10,847.844' GLM #11 Dummy 10313 0ts 'X0" Sliding Sle 111944' , m iti };.1 LInl Packer VII 10867 ' • 3.5 "X Nipple(2813."ID) 108 HX 10,£90 "107'52' EOF is 113.8E+13' H N--$R: 10,718- 11003 i + FISH Z 3- Tbp wJ"tY' NIpi'e 011,1224' (12.4.73) PSTG. 11024' TU- 11282' • X / fiNERGY PLF 8-1442 2 I E R G Y PRO EQ Cann ,., MOS C34-26 / '-rte KM 35 Cook Inlet, Alaska Wa tl1 t Imo: 77 MSL Logi. Conductor 3 #4 API $0.. 5 3,Z!OD O „of 2 ' '�� 4.7 * E.80 B id am. Set Spud :1163 • 2-319 Haler TE5 SSW 0 304' 4' Pup Jt, 2-38r 4.7* L84 8nd ELM 0 305 Surf Cag:10 314; 40.51tt, AS. As 2 15" 4.7'7! LB0 Bid EUE Sat 4732 °_ d elf 1504 Inc 2-3/8" 'up .11. 2 4. * L80 &d EUE 0 9595' 23/6" X Nipple (1.87!6" ID) 9+fir 4' Pup,it. 24/d" 4.7.91.50 Erd EuE O 9595' 1 A 2 4.70 1.110 erd EUE ti 04' _I 7" TIW H$14 - 180 Retrievable Plu ig 17735' 3 45 2.3#r 41* L80 8rd EUE § W73W 4i Pup J. 2-318" 4.7`* Leo Ord EUE 4) 9632' 2+3 r XN Nipple (1.799 •10) 9 Cr 0 9699' yy � /�. 4 ` Pup +1t. 2 -318" 4,7* LBO Ord EUE') 0832' t..o et+ 7"', N&) ETC F �l C. Sat 0 11,25W. 3 Y 2 ' D41f S8R Slabbed on 9618' Cmt w1 1200 ax, TOC a ?900' r 1» ,moo -. NW 2 Surface 6x47`1 !iJ•I I =>E3 2811 4711 - 8846. f0 E. itin=isw2A. lelipan 29* : 8815— 11,25W, mila=111 1 2 WEAN MUM _ ". Tb9z4C r I ; ' wtllav� I/I Pecker YJ1 4D Ma 9p ip"� t i MEM .! GR-GS: 9919 -26' & 9932-57' Man) 1 ID: GLI�A1U0 Du my 0 =5' f till _ 113,247' 256 1#.2A4 -30a XO Slicing Sleeve 0 10314 (Shut) 0, Uni- Pucker VII Co 10331' ► .r l HD-HE: 10,355 -55' 01.I41#10Dummy0 1104' •.1 X0 SPISMO sleeve a 10453 Down {l(11173) $ +� SS I. HE- hlF:1a.397.453 ( tZd) 1rn..P r4'1I,1 10,481' .I:4 M -- ; 11-HK :10,625- ' 9 GL* t1 Dummy W 1O' :- HK- RN(u): 10,547-044' XO 811ding Sleeve 117844' (SM) Urn-Packer vii 02 10382' 9+ ►g ' iiae,+ , 3-W X Nip,1e (2.813'10) 10873` '/ e P HN-HR 10 11000 PIM: 11024' ,, ��++'' l 15/1. 2` 3-W Tbg wtt "Q Woe 0 11,04' (12.4 - 75) .... I • o t CAMERON XTO PLATFORM C Will 34-25Equipment CURRENT WH 044-12 rir r46-1 7 , Mock Try* • with Integral and askillone1 WV Wing 4- .4* I 1.11 API AK Run with 2-14111 API AK Wing Valves an sling wit R.24 Ring Gaskets L '17 r tr .. .-' TLbing Hangar Us 3"Type H I3PV PrOfils • ..-, -,...:r I • _ In I J ....-.= Alyz say 17 1 '' 1 _.--. . ti. Oh__ 47' .. ,1 L '' p.. ;:. Lossanutst Casing Head "Pips 0 Compact 11" 3K (FP Clintp) Hub ill API AK 4010 Clamp) Hub Top I 10% R-23 fRODEFIED Ring Gat Bottom 4, - r .,,_.• IP R•83 Ring Gant* Tap Annulus Whoa as 2.1. API AK 1 - . . . tl R•24 Ring enlist ..,..e,.. 1 ... - J e [1- Ill I 1 i __ fr..:=:. t . - . . • s' 11" - = • • t. '14.6 • _ _ N: r Vrilt APIS( I 0: Re24 Ring Gasket V Ab --, • 11 4 I -I - 1 A'r 1 1 _ 1 •., t ` a" t • - '-=. 2' * Pr ] ia. ...._—_ -' . - ' ' R-24 RI . G . ' ' • 0 CAMERON xTo PLATFORM C Wall 34-25 PRODUCER REPLACEMENT EQUIPMENT 2012 Wok currently has a Cameron Type D Compact Wellhead Existing T' Casing will be cut to allow removal of the 0 Compact Housing. A new Casing Housing will be installed, the T lied back and a new Tubing Spool Installed. W. will also replace the Tubing Hanger, Adapter and Tree "Eguiginerrt, nfluure4 as show Irt 'Equipment tattgrifieured .as atioWt =1_6, 2 -1116 ,OOD Wing HWO and Pneumatic Trees configured the same S. axlsttrg ....__1 Actuated Wing valve with H;2 Choke to be equipment cujnnilv on Wells per Shipped separate from run of Tree ph,o ooraohe r )l f« ^ -1 P) RI� 165 00 t ' I ` L1 1 n me 2 -glib 5C]0 Tree _ 1—�,� '' - With 2-1/15 5K W ng I '" - V 1 . 4f1.1 t Replacement Tubmg Heac Adapter 1--r 7-1/18 x 2 4118 Stainless Adapter rr• -- Rep.a ument T,►ning Barge PN UNKNOWN 7 x 2.718 EUE Ord Stainless '� 7 : PN LIN KNOWN Rep a ntsr}s't Tubing Spec,: 0..I - -. t0 " CAMERON N 11"SK x 7 -1118 5K Top 1171 �=� '�' IVim (2) 21116 5K Valves "� 1 I - o- -. ..• • Leave one at the Annulus Valves PN Unkr►own p ' j , " 'ice ° , ;l open ended to allow line to be rigged NX Saturn Pre '' I _ ' �• f r O F ., a `` . --` r - - Reptaaemed Secanday Seal '}r PN UNKNOWN 4 ' Replatemer�t SI.;s as Replacement C.:ingg f lead '" � - PN UNKNOWN -- i • u.itAll ( PN UNKNOWN : - " a • • 11.311312 13 025 BOP' 5Gh.ma•rrc xro - ENERGY lm M.v DA srZ3P�6�2 _ "Itto Flor" o a &Millie ■ It 1 t ti Iii Hydril Fr , 13 513' 5.1i 13 6 6m Annular trouble ram R' ,sw.med foreman . l� 27.1. _ • if as' as Corm •*....... Poona* ors mss. • i 13 .x' liw Calm _.. , _� �. �. Hi - 1 • ....... ..., 1.i.aii.1 ii it oi . r� � .ii 3 hi 1U1 ller . l 1ATG7wuLaut 1. . a . 11 Fi/16 7 31 /V 3 iiir5m Stn Ern HMdra:14 Liana i Manual V; !di 13SSIn moor 13 VW' 3m 1 to .r 11 MA Eros with 6]/8^ cutlet Pala 1 } a �OF T� • 4 fr I //7, THE STATE Al Gil and s of Ll'1^ SKA Cservation C GOVERNOR SEAN PARNELL wR 333 West Seventh Avenue OF ALASY' Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 Alec Bridge SCANNED MAY 0 6 2013 Operations Engineer XTO Energy f — 0 1 9127 S Jamaica Street Englewood, CO 80112 Re: Middle Ground Shoal Field, E, F, G Oil Pool, MGS C34 -26 Sundry Number: 313 -215 Dear Mr. Bridge: 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. Commissioner r DATED this day of May, 2013. Encl. RECEIVED 4. STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION 01 Al c 21.013 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 11 AOGCC 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well IS • Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing IS , lime Extension ❑ Operations Shutdown ❑ Re - enter Susp. Well ❑ Stimulate ❑ Alter Casing 0 , Other. ❑ 2. Operator Name: XTO Energy / 4. Current Well Class: 5. Permit to Drill Number: v Exploratory ❑ Development El • 168 -019 - 3. Address: 9127 S Jamaica St Stratigraphic ❑ Service ❑ 6. API Number. ' glib 't Englewood, CO 80112 50 - 733 - 20093 - 5 �1 7. If perforating: 8. Well Name and Number. • What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ Middle Ground Shoal C34 -26 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 18756 • MGS E, F, G 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): • 11,282 9,908 • 11,024 9,692 NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,732' 10 -3/4" 1,732' 1,642' 3,130 psi 1,580 psi Intermediate Production 11,259' 7" 1,259' 9,889' 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • 9,919 - 11,000 8,720 - 9,672 2 -3/8" & 3 -1/2" L -80 & N -80 10,683 Packers and SSSV Type: 4 - 7" Guiberson Uni- Packer VII, Packers and SSSV MD (ft) and TVD (ft): 1 - 7" TIW HM -1 Retrievable Packer, 1 - Baker TE -5 SSSV Please see attachment • 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 • Exploratory ❑ Stratigraphic ❑ Development El , Service ❑ 14. Estimated Date for 4/21/2013 15. Well Status after proposed work: Commencing Operations: Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: 14.1V•13 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: 631-4•1 S- a,'1'- GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alec Bridge Email alexander bridcleaxtoenergy.com Printed Name Alec Bridge Title Operations Engineer Signature Phone (303) 397 -3608 Date 4/18/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 313 _ 2 1 3 ..... .... , Plug Integrity ❑ BOP Test [0 Mechanical Integrity Test ❑ Location Clearance ❑ Other: SOON pSc- 5c° G/ S A g 3000 PSL, ca.S i►+ ,2st*, 4rs C7 ", RBDMS MAY - 3 201, Spacing Exception Required? Yes ❑ No Subsequent Form Required: ( , `f 04- APPROVED BY //_...4? Approved by: COMMISSIONER THE COMMISSION Date: 5 / A' c-.3.,3 Submit Form and Form 10 (CMG I S t A j red applicat' n is valid for months fr the date of approval. An ents in Duplicate t� �t� • • • XTO ENERGY MGS C34 -26 Form 10 -403 Attachment Packer & SSSV depths ITEM MD (ft) TVD (ft) Baker TE -5 SSSV 305 305 TIW 7" HM -1 Retrievable Packer 9,753 8,568 Guiberson Uni- Packer VII, #1 9,880 8,680 Guiberson Uni- Packer VII, #2 10,331 9,079 Guiberson Uni- Packer VII, #3 10,481 9,213 Guiberson Uni- Packer VII, #4 10,662 9,374 A • • RECEIVED ENERGY /CL 2Q13 April 18, 2013 CC Alaska Oil and Gas Conservation Commission Attn: John Norman, Commissioner 333 W 7th Ave., Suite 100 Anchorage, Alaska 99501 -3539 RE: Form 10 -403, Application for Sundry Approval Objective: Repair 7" production casing Middle Ground Shoal C34 -26 Middle Ground Shoal Field: E, F, G Oil Pools Cook Inlet, Alaska API: 50- 733 -20093 XTO Energy herby submits its Application for Sundry Approvals to repair the 7" production casing in the Middle Ground Shoal C34 -26. Enclosed are the following attachments: 1. Form 10 -403 Application for Sundry Approval 2. Form 10 -403 Attachment (Packers and SSSV depths) 3. Summary Page 4. Job Procedure 5. Wellbore Diagram 6. Approved Sundry #312 -320 (original workover sundry) If you require additional information, please contact me at (303) 397 -3608. Sincerely, G 04/161 Z013 Alec Bridge, Operations Engineer CC: Sandra Haggard, Regulatory Analyst, (303) 397 -3672 XTO Energy Inc. • P.O. Box 6501 • Englewood, CO 80155 • 9127 S. Jamaica St. • Englewood, CO 80112 • (303) 397 -3600 • Fax: (303) 397 -3899 An ExxonMobil Subsidiary X T0 ERGY April 18, 2013 To: John Norman Guy Schwartz Victoria Ferguson CC: Scott Griffith Romeo Perez From: Alec Bridge RE: MGS C34 -26 Cook Inlet, Platform C 7" casing repair Addition to previously completed workover program XTO completed the workover on the MGS C34 -26 (Sundry #312 -320) to install a new gas lift completion and return the well to production on April 5, 2013. When lift gas was injected down the 7" casing x 2 -3/8" tubing annulus, pressure began to increase within minutes on the 10 -3/4" casing x 7" casing annulus. Gas injection was stopped, the surface casing pressure was bled off, and the well was shut in. The well is currently shut in and awaiting the testing and repair of the 7" casing. The most likely place for the leak is at 163', where a new connection was made as part of the wellhead replacement during the workover. However, the entire casing 7" casing string from 9,750' to surface will be tested. The 7" casing was pressure tested successfully during the recently performed workover. Please reference Sundry #312 -320 for the original scope of work, workover procedure, kill weight calculations, BOPE drawings, etc. A copy of the approved sundry is attached to this application for your reference. If you require additional information, please contact me at 303 - 397 -3608. Sincerely, a lt,&%;,“1(fy M11812013 Alec Bridge Operations Engineer • fto GY XTO ENERGY MGS C34 -26 - EAST FLANK PRODUCER COOK INLET, ALASKA 7" CASING LEAK REPAIR 04/18/2013 WELL DATA SURFACE CASING: 10 -3/4 ", 40.5 #, J55, BTC set @ 1,732'. Cmt w/1,550 sk. LONGSTRING CASING: 7" 23 #, 26# & 29# N80. Set @ 11,259'. Cmt w /1,200 sk. TOC @ 7,900' Surface — 4,711': 23# 4,711' — 8,646': 26# 8,646' — 11,259': 29# TUBING: 2 -3/8 ", 4.7 #, N80, 8rd, EUE @ 9,877' 3 -1/2 ", 9.3 #, N80, 8rd, EUE @ 10,683' PACKERS: 4 — 7" Guiberson Uni- Packer VII @ 9880', 10,331', 10,481' & 10,662' Guiberson packers set in 1973 1 — 7" TIW HM -1 Retrievable Packer @ 9,473' set 03/28/2013 PERFORATIONS: GR -GS: 9,919' — 26' & 9,932' - 57' HC -HD: 10,247' — 56' & 10,284' — 305' HD -HE: 10,355' — 65' HE -HF: 10,397' — 453' HI -HK: 10,526' — 40' HK -HN: 10,547' — 644' & 10,690' — 752' HN -HR: 10,786' — 11,000' FISH: 2' — 3 -1/2" tbg w /Q- Nipple @ 11,024' PBTD: 11,024' BHST: 170 Deg F BHP: ± 4,500 psi (SI WHP = 500 psi) 1 of 4 SMALLEST ID: 1.791" ID X Nipple @ 9,675' PRESENT STATUS: SI with 50 psi WHP and 380 psi CP OBJECTIVE: Repair 7" casing leak BACKGROUND: After performing the workover to return this well to production (Sundry #312 -320, AFE #1200385), pressure was noted on the 10 -3/4" x 7" annulus when lift gas was injected down the 7" x 2 -3/8" annulus, which indicates there is a leak in the 7" casing. The most likely place for the leak is the connection at 163' that was made as part of the wellhead change out during the last workover; however, the entire 7" string from 9,750' to surface will be tested. EQUIPMENT & MATERIALS REQUIRED: • 7" casing joint with guide skirt welded on (Olgoonik) • WL with CCL and string shot for casing back -off (Pollard) • 7" RBP (Halliburton) • 7" RTTS packer (Halliburton) • 7" casing cutter (Olgoonik) • 5 -3/4" Casing spear (Olgoonik) • 7 ", 26 #, L -80, BTC -M casing (TSA; exact amount will be dependent on location of leak) • New slips for 7" casing (Cameron) • 10.3 ppg CaC1 fluid (leftover from C24 -26RD) PROCEDURE: 1. MIRU derrick. 2. RU SL. RIH to bottom GL mandrel at 9,700'. Pull orifice valve. RD SL. 3. Kill well with 10.3 ppg CaC1 fluid (already mixed from workover on C24 -26RD) by pumping down tubing and circulating out tubing- casing annulus. Monitor well to ensure it is dead. 4. Notify AOGCC 48 hours prior to BOPE test. Set BPV. ND WH. NU riser and BOPE. Pull BPV and set two -way check. Ensure that BOPE has VPRs for 2 -3/8" — 3 -1/2" pipe. Pressure test BOPE to 250 psi and 5,000 psi. 5. RU to POOH and LD 2 -3/8" gas lift completion. Release packer. POOH and LD 2 -3/8" tubing with gas lift valves. Send packer to onshore to be redressed. 2 of4 . • 6. MU 7" RBP and 7" RTTS on 3 -1/2 ", 15.5# drill pipe. RIH. Set RBP at 9,750' (same location as production packer). PUH and set RTTS at 5,000'. Pressure test between RTTS and RBP to 2,000 psi for 30 minutes. Pressure test from RTTS to surface to 2,000 psi for 30 minutes. 7. If test from 5,000' to surface fails, release RTTS, PUH and reset RTTS at 2,500'. Test above and below RTTS (2,000 psi, hold for 30 minutes for each test). Continue moving RTTS up -hole and retesting until the leak is located. NOTE: If pressure test below 5,000' fails, continue moving packer down hole and pressure testing to locate the leak. Once the leak is located, stop before proceeding. Contact Alec Bridge before proceeding. 8. RIH to RBP. Release RBP. PUH and reset RBP 1,000' below the casing leak. Drop 500 lbs sand on top of RBP. POOH with drill pipe and RTTS. 9. MU 7" casing cutter on DP. RIH and cut 7" casing 40' below the wellhead assembly (cut must be BELOW the first collar so that the slips come out with the collar). POOH and LD casing cutter. 10. ND BOPE. ND tubing spool. 11. POOH with 7" casing and slips. 12. NU 13 -5/8" 3K x 13 -5/8" 5K spacer spool (spacer spool needs to be same height as tubing spool). NU BOPE. Install and test 7" rams. -ie,5f - 7" le -4 ks 4. 366o s� -- S 3•(3 13. RIH with ITCO 5 -3/4" spear (2.0" ID) and engage the top of the 7" casing. PU 5,000 lbs over string weight. RU Pollard WL. RIH with string shot and CCL. Apply recommended torque to 7 ". Fire string shot in collar ONE FULL JOINT BELOW THE LEAK. Backoff casing. POOH and LD casing. 14. RU casing crew. PU guided skirt joint and 7 ", 26 #, L -80, BTC -M casing. Slip skirt over the collar on casing stub. MU threads. Pressure test the connection against the RBP to 2,000 psi for 30 minutes. ND BOPE and spacer spool. Hang off the 7" casing in new slips in wellhead. Cut excess casing. NU tubing spool. 15. Notify AOGCC 48 hours prior to BOPE test. NU BOPE. Install VPRs for 2 -3/8" - 3 -1/2" pipe. Pressure test BOPE to 250 psi and 5,000 psi. 16. Re- pressure test casing to 2,000 psi for 30 minutes against RBP. 17. RIH. Wash off sand from RBP. Retrieve RBP and POOH. 18. RIH with TIW HM -1 retrievable packer on 2 -3/8" tubing as follows (NOTE: only change to completion is an additional 6' pup jt below packer; ensure packer has been redressed): 3 of 4 • • Item Length, Top Bottom Item 2 -3/8" 4.7# L80 8rd EUE 301 0 301 1 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 301 305 2 2 -3/8" Baker TE5 SSSV 1 305 306 3 2' Pup Jt, 2 -3/8" 4.7# 8rd EUE 2 306 308 4 2 -3/8" 4.7# L80 8rd EUE 9,402 308 9,710 5 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 9,710 9,714 6 2 -3/8" X Nipple (1.875" ID) 9 Cr 1 9,714 9,715 7 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 9,715 9,719 8 1 jt 2 -3/8" 4.7# L80 8rd EUE 33 9,719 9,752 9 7" TIW HM -1 Retrievable Packer L80 6 9,752 9,758 10 6' Pup Jt, 2 -3/8" 4.7# 8rd EUE 6 9,758 9,764 11 3 Jt 2 -3/8" 4.7# L80 8rd EUE 99 9,764 9,863 12 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 9,863 9,867 13 2 -3/8" XN Nipple (1.791" ID) 9 Cr w /RHCP 1 9,867 9,868 14 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 9,868 9,872 15 3 -1/2" x 2 -3/8" TIW SBR Stabbed on @ 8 9,872 9,880 16 9,872' 19. PU landing joint and stab 3 -1/2" SBR onto 3 -1/2" tubing stub. Pull SBR off seat. Mix 5 gal EC1447 (corrosion inhibitor) and 5 gal EC6112A (biocide) in 20 bbls filtered CaC1 fluid. Pump pill down tubing and under - displace 5 bbls from EOT. Stab SBR onto stub. 20. RIH SL. Prior to landing new tubing hanger, RIH and make 1.5" drift run to verify that SBR is stabbed onto tubing stub. RD SL. 21. Space out and make up and land new tubing hanger. 22. Drop bar (will seat in RHCP in XN- nipple). Pressure test tubing to 1,000 psi for 15 minutes. Continue to pressure up to 4,000 psi to set packer (follow TIW's setting instructions). Pressure test 5 13 tubing to 4,000 psi for 30 minutes. -1; e ;. ( m 17-- IA) Zap 23. Set BPV. ND BOPE. NU WH. Pull BPV. Set two -way check. Test wellhead to 5,000 psi. Pull two - way check. 24. RU SL. RIH and pull bar and RHCP. RD SL. 25. PWOGL. CUt 04- (IB/z0 Alec Bridge Operations Engineer 4 of 4 • • ) 1TO ACB 04 -09 -13 E N ERG Y CURRENT & PROPSOSED Completion MGS C34 -26 'f ` re KB: 35' Cook Inlet, Alaska Water Depth: 73' MSL Leg 1, Conductor 3 r Tbg: 2 -3/8" 4.7# L80 8rd EUE. Set: 03/28/13 API No.: 50- 733 - 2003 -00 Spud: 1968 / ` 4' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 300' i ��I. 2 -3/8" Baker TE5 SSSV @ 305' 4' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 306' 2 -3/8" 4.7# L80 8rd EUE Surf Csg: 10 3/4 ", 40.5 Ib, J55. 4' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 9695' Set @ 1732'. Cmt'd w/ 1500 sx. 2 -3/8" X Nipple (1.875" ID) 9 Cr @ 9699' 4' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 9695' 1 Jt 2 -3/8" 4.7# L80 8rd EUE @ 9704' 7" TIW HM -1 L80 Retrievable Pkr @ 9753' 3 Jt 2 -3/8" 4.7# L80 8rd EUE @ 9764' 4' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 9863' 2 -3/8" XN Nipple (1.791" ID) 9 Cr @ 9867' 4' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 9868' Longstring 7 ", N80 BTC. Set @ 11,259'. 3 -1/2" x 2 -3/8" TIW SBR Stabbed on @ 9872' Cmt w/ 1200 sx. TOC @7900' GLM MD TVD PORT PSC PSO 23# : Surface to 4711'. #1 2204 2050 12 942 1000 26# : 4711 - 8646'. #2 3804 3415 12 923 963 #3 4845 4320 12 903 , 934 29# : 8646 – 11,259'. #4 5622 5000 12 885 908 #5 6201 5509 12 863 886 , #6 6779 6010 12 842 864 %%/ /� #7 7357 6508 14 815 845 #8 7932 7002 14 793 822 Tbg cut @ 9872' #9 8511 7495 14 770 799 #10 9121 8016 14 747 775 Uni-Packer VII @ 9880' / ► � / #11 9700 8519 14 Orifice GR - GS: 9919 - 26' & 9932 - 57' (SQZ'd) I GLM #9 Dummy @ 10278' �'' 1WE1 HC HD: 10,247 - 256' & 10,284 XO Sliding Sleeve @ 10314' (Shut) / Uni - Packer VII @ 10331' � . 0 /001 HD-HE: 10, 355 -65' 0 r GLM #10 Dummy @ 10428' / // I • • I XO Sliding Sleeve @ 10463' (Shut) �j = HE - HF: 10,397 - 453' ( SQZ'd) SS is Upside Down (1973) , r Uni - Packer VII @ 10,481' Z HI -HK: 10,526-540' i GLM #11 Dummy @ 10610' 11.111 — HK- HN(u): 10,547 - 644' XO Sliding Sleeve @ 10644' (Shut) r, Uni - Packer VII @ 10662' P I► 3 -' /" X Nipple (2.813" ID) @ 10673' — HK- HN(I): 10,690 10752' rfi HN - HR: 10,786 11000' (CDQ FISH: 2' 3 Tbg w/ "Q" Nipple @ 11,024' (12 - 4 - 76) PBTD: 11024' I/ 4 TD: 11282' %///��///. 410 • • IT A_= /sNPARNELLGovERNoR v ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMPIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Maria Perez Regulatory Analyst Recvmu XTO Energy, Inc. 200 N. Loraine, Suite 800 SEP 0 4 au Midland, TX 79701 Re: Middle Ground Shoal Field, E, F, & G Oil Pool, MGS #C34 -26 Sundry Number: 312 -320 Dear Ms. Perez: 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. / Commissioner DATED this day f August, 2012. Encl. 110 111, TO E NERGY a subsidiary of ExxonMobil RECEIVED ` August 16, 2012 AUG 1 Alaska Oil and Gas Conservation Commission A � ^ � Attn: John Norman, Commissioner 'i 333 W. 7 Ave., Suite 100 Anchorage, Alaska 99501 -3539 Re: Form 10 -403, request for sundry approval Objective: Pull tbg, replace wellhead, and run new gas lift string. Middle Ground Shoal #C34-26 Production Well Middle Ground Shoal Field, E, F, & G Oil Pool Cook Inlet, Alaska API 50-733-20093-00-00 XTO Energy Inc. hereby submits its Application for Sundry Approval to pull tbg, replace wellhead, and run gas lift string. Enclosed are the following attachments: 1. Form 10-403 Application for Sundry Approval. 2. Cover Page 3. Summary Page. 4. Production Plot 5. Sub Surface Safety Valve Report 6. Deviation Survey. 7. Job Procedure. 8. Current Wellbore Diagram. 9. Proposed Wellbore Diagram. 10. Current Wellhead Schematic 11. Replacement Wellhead. 12. BOP Schematic. If you required additional information, please contact Paul Figel, Engineering Manager at A/C 432 -620- 6743. Sincerely, Maria L. Perez, Regulatory Analyst Tel. No. A/C 432 - 620 -4325 Copy to: Paul Figel, Engineering Manager 200 N. LORAINE, SUITE 800, MIDLAND, TEXAS 79701 • 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION °t APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 - , , 1. Type of Request: Abandon ❑ Plug for ReddB ❑ Perforate New Pool ❑ Repair Well ❑ I Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ©, Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ID Stimulate El Alter Casing Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. XTO Energy Inc. Development p Exploratory ❑ 168 -019 3. Address: Stratigraphic ❑ Service ❑ 6. API Number 200 N. Loraine, Suite 800, Midland, Texas 79701 50- 733 - 20093 -00 7. If perforating, dosest approach in poops) opened by this operation to nearest 8. Well Name and Number: j property line where ownership or landownership changes: REC V�� Spacing Exception Required? Yes ❑ No El Middle Ground Shoal C34 -26 9. Property Designation (Lease Number): 10. Field/Pol(s): ADL 18756 1 MGS E, F, G AUG 7 2012 11. PRESENT WELL CONDITION SU WARY (� Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): ,)M19 C rued): 11,282 9,908 11024 9892 NA NA Casing Length Was MD 'ND Burst Collapse Structural Conductor Surface 1732 10 3/4 1732 1642 3130 1580 Intermediate Production 11259 7 11259 9889 6340 3830 Liner J I Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9919 -11000 8720 - 9672 3-1/2" N-80 10683 Packers and SSSV Type: 4- Guiberson Uni -Pkr 7, Otis SSSV Packers and SSSV MD (ft) and TVD (ft): See Attached 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program El BOP Sketch El Exploratory El Development El Service ❑ 14. Estimated Date for Nov. 2012 15. Well Status after proposed work: Commencing Operations: Oil IS Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Figel, Engr 432 - 620.6743 Printed Name Maria Perez Title Regulatory Analyst Signature /1 Phone 432 - 620-4325 Date 8/16/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 34,3...3A0 Plug Integrity ❑ t Vast Mechanical Integrity Test ❑ Location Clearance ❑ Other: rc :RAP - �* - Subsequent Form Required: APPROVED BY COMMISSIONER - ��� Approved by: FF THE COMMISSION Date: g 1/ Form 10-403 Revised 1/2010 OJi L� CITE Submit In Duplicate i Form 10-403 Packers and SSSV MD (ft) and TVD (ft) MD TVD SSV 290 290 Pkr 1 9880 8680 Pkr 2 10331 9079 Pkr 3 10481 9213 Pkr 4 10662 9374 /TO ERGY August 15, 2012 To: John Norman Guy Schwartz Victoria Ferguson Cc: Scott Griffith Scott Landon From: Paul Figel Subject: Workover for MGS C34 -26 (168 -019): Return Shut -in Well to Production. Obiective: The objective for the workover proposed for the C34 -26, Located on Platform C, Cook Inlet is to replace the current 3-1/2" gas lift string with 2 -3/8" tubing and return the well to production. The well currently has 4 Guiberson retrievable packers that were installed in 1973 to isolate the various zones. Past experience has shown that these Guiberson packers require milling out as they will not release. Therefore, for economic purposes, the 3 -1/2" tubing will be cut above the existing top packer and will be conjoined with a PBR below a new packer. This well is currently equipped with an outdated product (Type D Uni- Compact Head) that Cameron no longer supports nor has adapter parts to allow for a new tubing hanger to be installed. Therefore, the entire_ existk wellhead will be removed and replaced with a conventional multi - compartment wellhead. This will be done as outlined in the procedure requiring that the 7" Longstring be cut below the deck to allow the removal of the lowermost casing head section. Approximately 150' of the 7" casing will be replaced and brought back to surface and hung off in a new casing head with slips. This will allow a new tubing spool to be installed. Well History: This well was drilled in the East Flank in 1968 and completed in the 13 separate Hemlock intervals from the GR to HR. The well IP'd 1970 BOPD, 24 BW & 689 MCF. The C34 -26 was offset to injectors C -Line (4000 BWIPD) and C23 -26 (3500 BWIPD) as of 1969. A production log was run in July 1971 as the water jumped from 125 to 500 BWPD and oil fell 1500 to 800 BOPD. The survey showed 8 of the 13 intervals contributed less than 50 BPD. Therefore, in Dec 1971 an acid job was pumped which, according to the 1972 production log, had minor inflow effects but verified that the HE -HF, HI -HK & HK -HN were contributing +90% of the water. The well was recompleted in 1973 with 4 isolation packers and sliding sleeves to selectively produce: 1: GR -HD (open), 2: HD -HF (closed), 3: H1 -HN(u) (open), 4: HI -HN(1) (open), & 5: HN -HR (open), however, the sliding sleeve for the HD -HF was installed upside down was closed when thought to be open from 1973 -'76. This was discovered in 1976 when slickline tried to "close" the SS but actually opened the sleeve causing the well to kick and flowed 1600 BPD @ 1700 psi WHP. The top 3 SS were closed #1 (GR -HD), #2 (HD -HF) and #3 (HI- HN(u)) and the • 2 well tested 152 BOPD & 102 BWPD from the HK -HN (1) & HN -HR. In Dec '76, these zones were reperforated and gained 60 BOPD without any water. The C34 -26 lost the injection support of the C -line well in 1981, 5000 to 1800 BWIPD, and then again in 1984 when the C23 -26 had the HC -HN cement squeezed dropping support to 300 BWIPD. See attached Production Plot. The last treatment was done in 1985 with a small 2000 gal xylene -acid job performed with coil tubing which had minimal effects. The well was shut -in in 1988 due to economics only making 9 BOPD & 81 BWPD. The cumulative production is 3.3MBO. The anticipated date for operations start up is November 2012. Please contact me at 432 -620- 6743 with any questions or concerns. Sincerely, 904-ut rtipi Paul Figel Engineering Manager WORKOVER SUMMARY for C34 -26 Scone of work: Cut the 3 -1/2" production tbg below the top sliding sleeve @ 9841'. POOH with the current 3 -1 /2" gas lift string and replace with a 2 -3/8" gas lift string that will stab onto the tbg stub @ ±9846' with a PBR assembly. The current lowermost casing head section will be replaced with a new conventional casing head that will allow for the installation of a new tubing spool and tubing hanger. Current Well Status: Shut -in 1988. Last prod was 9 BO & 81 BW. SI WHP = 500 psi. Well Info: See Attached Procedure & TVD Survey. SSSV test — see attachment. MASP: Prod is 90% Water Cut based on last prod @ 9 BO & 81 BW. 8.4 ppg FIW = 0.437 psi/ft 34 API = 0.3702 psi/ft. Mid Perf TVD: 9192' Top Perf TVD: 8715' BHP = [(0.1)(0.3702 psi /ft)(9192') + (0.9)(0.437 psi /ft)(9192')] + 500 psi = 4455 psi Phyd = (0.1)(0.3702 psi /ft)(8715') + (0.9)(0.437 psi/ft)(8715') = 3751 psi MASP = 4455 — 3751= 704 psi Kill Weight: 4455 psi = (0.052) (8715' Top Perf TVD) (x, ppg) x = 9.8 ppg + 0.5 ppg = 10.3 ppg mud Mud Recipe will be 8.4 ppg FIW + 112 lbs/bbl CaC12 MIT Info: NA as a producer BOP Ram Configuration: VPR for 2 -3/8" to 3 -1/2 ". Schematic Attached. Workover Rig: XTO derrick is a permanent rig on Platform C. Contact Info: • Operations Engineer: Paul Figel, XTO Energy, 432 -620 -6743, paul figelcxtoenergy.com • Superintendent: Scott Griffith, XTO Energy, 907 -776 -2506, scott griffjh(aZ,xtoenergy.com <Arrbiguas' 10000 7 - NCCLEC UNDSLIQyLEM_ - _ —. - - . '81 Offset Inj C -Line SI '73 Roper( + Set !so Pkrs (SS HD -HF Closed) z 1000 _ ' 84 Offset Inj C23-26 , SQZ HC -HN +Set ISO Pkr • 500 f ' 1 r 1 i 1 I l� i 100 1\111 • , II:. , , I { rill".111 5o a _ � • • A � t ! � r 1 nt ,0 i3 o 11 10 - VNELL: MGS (E) 023-26 (IRO, MGS (E) C34-26, MGS CLINE (INJX3) 1 a a • - CD Oil F o - CDV1tr 5 - CD Gas -- CD Vltrtrj ■•■•• co Inj Press Test_BOPD Alade - 0 Teg_BV1PD_Alaa G Test MCFPD Alaska 1968 69 70 71 72 1 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 Ede Cum Oil 3300148.000 Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: XTO Energy Submitted By: Barney Phillips Date: 5/20/2012 Operator Rep: Barney Phillips Field/Unit/Pad: MGS XTO C Platform AOGCC Rep: Matt Herrera Separator psi: LPS 68/68 LIPS veil Das Picts WV SSW - keitfst/S7 lie We Type Well des Gas L r 1 Waiver Well Permit Separ Set LIP Test Test Test Date Passed Retest o , w,o, GINJ, Inner Outer Tubing Yes/No Yes/No Number Number PSI PSI Trip Code Code Code Or Date Shut In ca►s, CYCLE, s. PSI PSI PSI C12 -23 1900200 68 37 38 P P P OIL 100 Yes No C13 -13LN 2022130 _ 1/1/2006 SI No No C13 -23 1880990 68 37 38 P P P OIL 95 Yes No ill C13A -23 1901060 P P OIL 90 Yes No C21 -23 1890870 _ P P OIL 95 Yes No C21 -26 1890040 P . P OIL 100 Yes No C21A -23 1910440 P P OIL 95 Yes No C22 -23 1880160 12/19/2004 SI Yes No C22 -26RD 1760650 5/5/2012 SI Yes No C22A -26LI 2041820 P P OIL 85 Yes No C24 -26RD 1790620 4/1/1992 SI Yes No C31 -26RD 2041400 P P OIL 90 Yes No C32 -23LW 2020340. P P OIL 75 Yes No C34 1196. 1 -F 1 1i11 19 _ No � C42 -23 1780240 P P _ OIL 95 Yes No C43 -14 1881320 P P OIL 3425 No No Wells: 11 Components; 24 Failure 0 Failure Rate: 0.00% ❑na" Remarks: • PLB 01/26/11 Page I of 1 SVS MOS C Platform 5- 20- 12.xls • I 1 • ' . ........ C Platform, Well C34-26 • . -. DITEQ I Alaska State Plane • , I Coordinates Measured Angle Azimuth ND-RI TVD X Y N / -S E / -W DLS Vert. Sec SVY# 6- - . - • des; ft : Subsea ft ft ft ft deg/100 ft ft Tie-In 0.00 0.00 0.001 0.00 -105.00 231364.82,2474232.49 0.00 0.00 0.00, 0.00 1 75.00 0.08 209.00 75.00 -30.00 231364.79 2474232.44 -0.05 -0.03 0.11 0.01 2 100.00 0.17 314.00 100.00 -5.00 231364.76,2474232.45 -0.04 -0.06 0.82 0.05 3 125.00 0.25 40.00 125.00 20.00 231364.77 2474232.52 0.03 -0.05 1.17 0.08 4 150.00 0.08 41.00 150.00 45.00 231364.82 2474232.57 0.09 -0.01 0.68 0.03 5 175.00 0.17 45.00 175.00 70.00 231364.85 2474232.61 0.13: 0.03 0.38 0.01 6 200.00 0.17 41.00 200:00 95.00 231364.91 2474232.87 0.181 0.08 0.05 -0.02 7 22546 0.08 21.00 226.00 120.00 231384.94 2474232.71 023 111 139 -0.04 8 250.00• 0.081 319.00. 250.60' 145.00 23136493,2474232.74 025 111 133 -ad 9 275.00 „ 0.281 309.001 275.00 170.00 231364.882474232.79 0.30! 0.05 0.69 0.05 10 300.00 0.331 259.001 300.00 195.00 231364.77 0.32 r -0.08 1.02 0.16 11 325.001 0.421 218.00; 325.00 220.00 231364.64 0.241 -0.19 1.10 0.25 • 12 350.90 0.42 230.001 350.00 245.00' 231384.51 2474232.80 0.11 -0.31 0.35 0.33 Tie-In 363.00: 133; 248.001 363.001 258.00; 231364.44 247423258 108 41381 1.13 -112 1 400.001 0.751 23.00 400.00, 295.00 231364.4412474232.74 0.24 -0.39. 2.73 -0.30 2 500.00' 3.501 86.00 499.92 394.92 231387.52 2474234.51 2.09 2.86 3.00 -1.68 3 800.00 5.25. 86.00 599.83, 494.63 231374.91 2474235.91 3.651 10.01 2.30, -2.16 4 700.00 7.001_ 131.00 699.11 594.11 231383.99 2474232.02 -0.031 19.18 4.95! 2.81 5 800.00 725L 154.00 798.36 693.36 231391.14 2474222.18 -9.701 26.55 2.84 13.44 6 900.00 10.501 174.00 897.17 792.17 231394.522474207.36 -24.44; 30.27 4.441 28.56 7 1000.00 14.751 174.00 994.73 889/3 231396.31 2474185.58 -46.18; 32.55 4.25 5040 8 1100.00 18.00 175.00 1090.66 985.88 231398.35 2474157.47 -74.24 35.23 3.26 78.55 9 . 1200.00 22.00 1 /6 to 1184.61 1079.61 231400.55 2474123.35 -108.30; 38.21 4.00_,. 112.69 10 1300.00 26.00! 175.00 1275.95 1170.95 231403.17 2474082.77 -148.81 41.75 4.001 153.29 11 1400.001 30.50 175.00 1364.02 1259.02231406.23 2474035.55' -195.95 45.88 4.50L 200.53 12 1500.00 32.001 174.00: 1449.50 1344.50 231410.03' 2473983.81. -247.591 50.86 1.591 252.34 13 1600.001 32.00 174.00 1534.31 1429.31 231414.37 -300.29 56.40 0.001 305.29 14 1700.00 31.75 174.00 1619.23 1514.23.231418.69 2473878.37 -352.80 61.92_ 0.251 358.05 15 1800.00 30.50d 174.00' 1704.83 1599.83 . 231422.93:2473828.88 ! -404.21 67.32 1.251 409.70 16 1900.00 30.50 172.00: 1791.00 1888.001231427.96 2473776.381 -454.58 73.50 1.02' 460.43 17 2000.00 31.50 173.00 1878.71 1771.71 231433.5212473725.16 -505.64 80.22 1.121 511.93 18 2100.00 31.25 173.00 1982.09 1857.09 231438.68, 2473673.36 -557.32 86.57 0.26. 563.98 f 19 2200.00 32.00 172.00 2047.24 1942.24 231444.3512473621.15 -609.301 93.41 0.92 616.41 20 2300.00: 32.001 170.00 2132.05 2027.05 231451.4412473588.72 -861.831 101.70 1.06 889.39 21 2400.00. 32.25 , 172.00 2216.74 2111.74 231458.56i 2473516.03 -714.151 110.02 1.09 722.55 22 2500.00' 32.75 172.00 2301.08 2196.08 231464.8312473462.67 -767.361 117.50 0.50 776.28 23 2600.00; 33.501 171.00 2384.83 2279.83 231471.68 2473408.46 -821.401 125.58 0.93 830.93 24 2700.00: 34.001 171.00 2487.97 2382.97 231479.12 2473353.40 -876.27, 134.27 0.50 886.48 .25 2800.00 , 34.50 172.00 ; 2550.83 2445.63 231486.1612473297.57 -93 142.58 0.75 942.76 _ 26 2900.00 32.25 173.00 2634.14 2529.14 231492.1212473242.88 -986.47 149.78 2.32 997.76 27 3000.00 29.75 183.00 2719.90 2614.90 231492.90 2473191.55_ -1037.77 161.73 5.72 1048.80 Tie-In 3133.00 28.75 180.00' 2835.95 2730.95 231489.70 2473128.57 -1102.71 150.00; 1.31 1091.32 1 3269.00 29.25 179.00 2954.90 2849.90 231488.78 2473080.74: -1188.64 150.58 0.51, 1157.08 2 3424.00 30.25 17.00' 3089.47 2984.47 231489.73 2472983.85 -1245.50 153.291 0.91 1233.82 3 3580.00 31.25 177.00 3223.54 3116.54 1231492.10 2472904.12 -1325.15 157.46 0.64 1312.87 4 3731.00 30.25 178.00' 3353.31 3248.311231493.72 2472828.94' -1402.28 160.841 0.74 1389.64 5 3888.00 3025 178.001 3488.93 3383.931231494.88 2472747.851 -1481.32 163.601 0.00 1488.38 6 4111.00 30.50 178.00: 3681.321 3576.321231496.05 2472635.10 -1594.02 167.541 0.11 1580.59 7 4204.00 30.25 175.00 3781.56 3656.56.231497.85 2472588.13 -1840.94 170.40 1.65 1627.25 8 4424.00 29.50 177.00 3952.33 3847.33! 2315C0.0212472478.68 -1750.24 178.07 0.57 1735.87 9 4579.00 29.25 178.00 4087.40 3982.40 231504.61 °i472402.67 -1826.20 181.39 0.36 1811.47 10 4797.00 28.75 179.00 4278.07 4173.07 -1931.85 184.16 0.32 1918.75 11 5016.00 28.25 181.00 4470.53° 4385.531231502.6212472192.53 -2036.33 184.17 0.49 2021.03 12 5112.00 28.00 183.00 4555.20 4450.201231500.0212472147.36 -2081.55 182.60 1.02 2066.26 13 5204.00 27.75 184.00 4838.52 4531.52 231496.422472104.50 -2124.48 179.97 0.58 2109.27 14 5328.00 29.00 181.00 4745.63 4840.83231492.54 2472045.721 -2183.34 177.44 1.53 2168.17 .1 • • !Measured ' . e Azimuth TVD-RKB TVD X 1 Y N I-8 E /...W I DLS 1 Vert. Sec SW4k 1 Depth . - . deg ' ft Subsea - ft 1 ft ft ft : deg/100 ft' ft 15 . 5411.00 30.00 183.00 4817.87 4712.87 231490.18! 2472004.92 - 2224.18 176.0' 1.69J 2209.02 16 5605.00 29.75, _ 182.00. 4986.09 4881.09 231483.76 2471908.51 - 2320.72 171.781 0.291 2305.64 17 578200 28.75 185.00 5140.53 503653 231476.56 2471822.35 - 2407.02 166.54' 1.001 2392.10 18 5948.00 28.25 188.00 5286.42 5181.42 231465.82 2471743.90 - 2485.70 157.59 0.911 2471.18 19 6136.00 28.50 184.00 5451.85 5348.85j231454.48 2471655.32 -2574.51 148.27' 1.021 2560.40 20 8294.00 29. 75 187.00' 5589.87 5484.87'231445.34 2471578.99 2851.03 140.86' _ 1.22' 2637.23 21 8340.00 29.75 188.00 5629.81 5524.81 231441.84.2471558.43 - 2673.68' 137.88 1.08 , 2860.00 22 8511.00 _30.001 192.00 5778.10 5673.10 231425.15' 2471472.96 - 2757.50 123.09 1.17: 2744.59 23 8834.00 30.00 j 191.00 5884.62 5779.62 231411.52 . 2471412.99 - 2817.76 110.83 0.41 2805.50 24 6791.001 30.50' 189.00 8020.25 5915.25 231396.03! 2471335.44 2895.84 97.10 0.72 2884.08 25 ' 6917.001 30.75 189.001 6128.68 8023.88 231384.55' 2471272.29 - 2959.04 87.06 0.20 _ 2947.98 28 7109.00 3025 192.001 6294.12 8189.12 231364.64 , 2471176.93 - 3054.83 69.33 0.83 304488 27 7204.00 30.75 196.00. 6375.98 6270.98 231351.91 2471130.45 - 3101.59 57.68 2201 3092.07 28 7265.00 30.00 189.00 6428.62 6323.82 231344.54 2471100.55 - 3131.65 50.97 5.93 3122.49 29 ' 7298.00' 30.75 187.00 6455.37 6350.37 231342.01 2471085.08 - 3147.17 48.791 4.06 3138.12 30 7424.00 30.50 184.00 6565.52 6480.52;231334.28 2471020.35 - 3212.06 42.54 1.214 3203.27 31 7579.00 3000 187.00 6699.42 6594.42' 231325.05 2470942.84 4289.76 35.07 1.03: 328128 32 7763.00; 31.00 187.00 8857.96 8752.981231311.56 2470850.44 - 3382.45, 23.89 0.54- 3374.50 33 7987.00. 31.50 187.00 7049.46 6944.46 231294.78 2470735.45 -3497.79 9.53 0.221 3490.50 34 j 8067.00 31.25 188.00 7117.78 7012.76' 23128 2470694.29 - 3539.08 4.09 _ 0.721 3532.05 f 1 35 8214.001 31.50 189.00 7243.27 7138.27 231275.38 2470618.88 - 3614.77 -7.22 0.39 ; 3608.29 36 8288.00' 32.251 189.00 7289.13. 7184.131231270.28 2470590.83! - 3842.94 -11.88 1.39 3636.88 37 8393.00 32.25' 189.00, 7394.84 7289.84 1 231258.35 2470525.20 - 3708.82 -22.12 0.00 3703.08 38 8649.00 31.50 191.00' 7812.24 7507.24 2470392 - 3841.94 -46.561 0.51 3837.39 39 8880.00 30.75 191.001 7809.99{ 7704.99 231206.43 2470275.99 3959.15 - 68.35, 0.32 3955.79 40 9033.00 30.25 194.001 7941.82 7836.82 231187.93 2470200.60 - 4034.94 - 85.131 1.05 4032.48 41 9202.00 30.75 195.00 8087.44) 7982.44 231184.56 2470118.08 - 4117.98 -106.611 0.42 4116.58 42 9324.001 30.50 191.00 8192.431 8087.43 231149.21 2470057.89 - 4178.501 - 120.60 1.68 4177.96 43 9438.00 29.75 195.00 8291.051 8186.05 231135.10 2470002.47 - 4234.23' - 133.44 1.88 4234.37 44 ' 9609.00 28.50 197.00 8440.43 8335.43 231110.38 2489923.01 -4314.231 - 156.35 0.93 4315.64 45 9731.00 28.00 200.00 • 8547.90 8442.90 231090.83 2489888.70 4388.98 - 174.85 1.23 4371.41 48 __ 26.75 195.00 8581.65 8476.65 231085.19 2469852.17 4385.62 - 179.92 6.88' 4388.35 47 9830.00 26.25 192.00 8836.24 8531.24 231078.23 2469825.87 - 4412.08 - 186.28 2.34 4415.15 48 1002400 2825, 188.00 8808.72 8703.72 23106094 2469738.80 - 4499.53 401.59 1.40. 4503.38 49 10094.00 29.00 187.00 8870.18 8765.16 231055.81 2469705.66 -4532.77 - 205.96 1.27 4536.83 50 10244.00 28.00' 187.00 9001.98 8896.98 231045.47 2489634.84 - 4603.81 - 214.89 0.67! 4608.27 51 10372.00 27.251 187.00 9115.39 9010.39 231036.90 2469576.11 -4862.72 -221.92 0.59; 4667.52 52 10516.00 26.00' 190.00 9244.12 9139.12.231025.95, 2469512.53 - 4726.53 - 231.42 1.27 4731.79 53 10647.00 27.751 190.00 9380.97 9255.971231014.35 2469454.47. - 4784.85 - 241.70 1.34 4790.63 54 10769.00 28.25; 192.00 9468.89 9363.69 231002.13 2489398.52' - 4841.06 452.64 0.87 4847.42 55 10926001 31.75, 190.00 9604.84. 9499.64 230985.48 2469321.83; 4918.11: - 267.541 2.32 4925.24 56 . 11015.00, 33.00' 194.00 9679.81, 9574.81 230974.562489275.48i -4984.701 - 277.471 2.79 4972.35 57 11173.00 29.75. 197. 001 9814-70. 9709.70 230950.821 4469198.74 1 3043.96 - 299.351 2.28 5052.82 58 ! 11282.00! 29.25! 199. 001 9909. 57 9804.57 230933.0912469146.09! - 5095.00 - 315.921 1.01 5104.79 2 • • X T0 ERGY XTO ENERGY INC. MGS C34-26 COOK INLET, ALASKA — EAST FLANK Return Well to Production Procedure WELL DATA: SURFACE CASING: 10 40.5# J55 BTC. Set @ 1732'. Cmt w/ 1550 sk. LONGSTRING CASING: 7" 23, 26 & 29# N80. Set @ 11,259'. Cmt w/ 1200 sk. TOC @ 7900' Surface — 4711':23# 4711 — 8646': 26# 8646 — 11,259': 29# TUBING: 3 -%2" 9.3# N80 8rd EUE @ 10,683'. PACKERS: 4 ea 7" Guiberson Uni- Packer VII @ 9880', 10,331', 10,481' & 10,662'. Pkrs set in 1973. PERFORATIONS: GR-GS: 9919 — 26' & 9932 - 57' HC -HD: 10,247 — 56' & 10,284 — 305' HD -HE: 10,355 — 65' HE-HF: 10,397 — 453' Hl -HK: 10,526 — 40' HK -HN: 10,547 — 644' & 10,690 — 752' HN -HR: 10,786 — 11,000' FISH: 2' 3 -1/2" tbg w/ Q Nipple @ 11,024' PBTD: 11,024' BAST: 170 Deg F BHP: ±4500 psi (SI WHP = 500 psi) SMALLEST ID: 2.813" ID X Nipple @ 10,673' PRESENT STATUS: SI w/ 500 psi WHP & 350 psi Csg Press. OBJECTIVE: Replace 3 -1/2" GL string w/ 2-3/8". • AFE # 1200385 • Prior to Workover, Slickline will run gauge ring to determine the condition of the tbg ID for WL jet cut. If tbg is scaled up, Coil tbg will be used to clean -out the tbg ID. • The entire D Compact Wellhead will be replaced which will require cutting & replacing the top 150' of 7" casing. • Need 11" a 13 -5/8" clamp adapter for BOP. 8 -14 -12 Y:1PI.Elala:lusa\Pmeedures1C34- 261034-26 RWTP Procedure 8- 14- 12.doc • • 2 Equipment: • RHCP Plug (Pollard) Installed in 2 -3/8" XN. • 4' drop bar w/ ball (Pollard) Materials Rqd: • 5 gal WC 1447WR Corrosion Inhibitor (Nalco) • 5 gal EC6112A Biocide (Nalco) • 100 bbl Gel Pill (2 #/bbl FloZan + 3 gal Greencide) (Provided by MI) • 67,000 lbs CaC12 (112 lbs/bbl FIW to build 10.3 ppg) Maintain MW from last well. 8 -14-12 Y :U'1.F UdaskaTrocedures1C34 -261r 4-26 RWTP Procedure S-14-12.doe • 1 3 PROCEDURE: 1. Bleed -off well to header. 2. RU Slickline & lubricator. RIH w/ 2.70" gauge ring to X nipple @ 10,673'. Reduce gauge OD if the 2.70" will not get DH. RIH w/ pulling tool to GLM #8 @ 9835'. Latch & POOH the dummy valve. RD lubricator. 3. MIRU Derrick. Mix up 400 bbl 10.3 ppg CaC12 mud (use from last WO). Circ to kill well through GLM #8 @ 9835'. Take wellbore fluids to disposal well and recover /maintain the 10.3 ppg Salt mud. 4. SD & monitor well for 60 minutes to make sure well is dead. 5. Notify the AOGCC 48 hrs prior to BOP test. Set BPV. ND WH. Set 11" 5K x 13 -5/8" clamp aa'apter. NU riser & BOP's. Pull BPV's & set 2 -way check valve. Press test BOP's to 250 psi & 5000 psi Send D Compact WH to OS for scrap. 6. MI 11,400' 3-1/2" 15.5# S135 drill pipe & 6 ea 4 -3/4" DC's. 7. MIRU Pollard WL. RIH w/ Radial Torch cutter & CCL. Cut the tbg ±5' below the SS @ 9841'. POOH. Observe the quality of the cut tbg as per Step #21 if stub will require a dressing. Leave WL on board for Step #17. 8. RU slips & tongs for 3 -1/2" tbg. POOH & LD 3 -1/2" tbg w/ 8 GLM's while checking for NORM. Send tbg & GLM's to onshore to be sold for scrap. Casing Cut for Csg Spool Removal: 9. MI 4 jts 7" 29# L80 BTC. 10. RIH w! HOWCO 7" 23# RBP & set @ 500'. Close pipe rams & press test to 1000 psi. POOH. Drop 500 lbs (20') of sand on top of RBP. 11. MU 7" casing cutter on DP. RIH & cut the 7" csg ±20' below the WH assembly. Circ out any gas. POOH & LD cutter. 12. ND BOP's. 13. Remove the bottom clamp from bottom of D Compact WH. LD WH w/ casing hanger & the 20' 7" casing stub. 14. NU new Cameron clamp x flange casing head. 15. NU BOP. 16. Press test the new clamp against the RBP to 3000 psi for 30 min. 8 -14 -12 Y:\ PLF' alaska \Proccdures \C34- 26 \C34 -26 RWTP Procedure 8- 14- 12.doc • s 4 17. RIH w/ 5 -3/4" ITCO Spear w/ 2.0" ID and engage the top of 7" & PU 5000# over string wt. RU Pollard WL. RIH w/ string shot & CCL. Apply recommended torque to 7 ". Fire string shot in collar between 100 -150'. Backoff casing at collar. POOH & LD ±3 jts csg, 18. RU Casing Crew. MU Triple Connector screw -in sub to 7" Csg. RIH w/ new 7" Csg & screw into collar. Screw on 7" swage w/ 1502 2" connection. RU mud pump and press test the 7" connection against the RBP to 2000 psi for 30 min. Bleed -off press. RD BOP's. Hang off 7" on slips in WH, make cut and install new Cameron Tubing Spool. 19. Notify the AOGCC 48 hrs prior to BOP test. NU BOP's. Set WH test plug in tla spool. Press test BOP's to 250 psi_& 5000 psi. 20. RIH and wash off sand & retrieve the 7" RBP @ 500'. 21. Based upon results from Step #7 - RIH w/ dress -off mill to dress off top of the 3 -1/2" tbg stub @ 19846'. BHA to consist of mill, casing scraper for 29# & MAGTRAP. LIGHTLY tag up on tbg stub @ 9846'. Dress-off tbg stub as per instructed. Reverse circ 20 bbl gel sweep. Make a casing scraper run as minimum if tbg stub dress - off is not necessary. 22. RIH w/ How 7" RTTS packer to 9735'. CCL has collars @ 9719' & 9763'. Est circ w/ FIW. Set pkr. Perform MIT on 7" x DP annulus to 2000 psi Monitor press for 30 min. POOH & LD DP. 23. MI 10,200' 2 -3/8" 4.7# L80 8rd EUE tbg (inc13% excess). 24. RIH w/ TIW 7" HM -1 Retrievable Packer on 2 -3/8" 4.7# L80 8rd EUE tbg and land as follows: Item Length, ft Top Bottom 2 -3/8" 4.7# L80 8rd EUE 300 0 300 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 300 304 2 -3 /8" Baker TE5 SSSV 1 304 305 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 305 309 2 -3/8" 4.7# L80 8rd EUE 9,386 309 9,695 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 9,695 9,699 2 -3/8" X Nipple (1.875" ID) 9 Cr 1 9,699 9,700 _ 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 9,700 9,704 1 jt 2 -3/8" 4.7# L80 8rd EUE 31 9,704 9,735 7" TIW HM -1 Retrievable Packer L80 4 9,735 9,739 3 Jt 2 -3/8" 4.7# L80 8rd EUE 93 9,739 9,832 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 9,832 9,836 2 -3/8" XN Nipple (1.791" ID) 9 Cr 1 9,836 9,837 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 3 9,837 9,840 3 -1/2" x 2 -3/8" TIW SBR Stabbed on @ 9846' 6 9,840 9,846 8 -14 -12 1': \PLF\alaska \Proccdures \C34- 26 \C34 -26 RWTP Procedure S- 14- 12.doc i 5 Gas Lift Design GLM MD TVD PORT PSC - PSO #1 2198 2050 12 942 1000 #2 3786 3400 12 923 963 #3 4822 4300 12 903 934 #4 5621 5000 12 885 908 #5 6192 5500 12 863 886 #6 6768 6000 12 842 864 #7 7348 6500 14 815 845 #8 7930 7000 14 793 822 #9 8517 7500 14 770 799 #10 9101 8000 14 747 775 #11 9677 8500 14 Orifice Each GLM to have a 4' Pup Jt on top & 6' Pup Jt on bottom. 25. PU landing jt & stab 3 -1/2" SBR onto 3 -1/2" tbg stub at 9846'. 26. Pull SBR off seat. Mix up 20 bbl biocide/pkr fluid pill to contain 5 gal Nalco WC1447WR + 5 gal EC6112A in 20 bbl FIW. Circ pill down tbg w/ FIW. Under - displace pill by 10 bbl inside the tbg. Set down SBR. 27. Space out & make up and land new Tbg Hanger. Run in lock screws to energize hanger seal. 28. RU Slick line & press test lubricator to 4000 psi. RIR w/ 1.5" tool to 8200' to verify the SBR is stabbed onto 3 -1/2" tbg sub @ 9846'. 29. RIH w/ PXN plug & set in XN nipple @ 9836'. Press test tbg to 1,000 psi for 15 min. Monitor falloff. Cont to press up to ±3,500 psi to set pkr. Hold 4,000 psi on the tbg for 15 min. POOH w/ SL. 30. Set BPV. ND BOP's. NU WA w/ new tbg head adapter. Pull BPV. Set 2 -way check. Test WH to 5,000 psi. Pull 2 -way check. 31. RU SL. RIH & pull the PXN plug. RD SL. PWO gas lift. Paul Figel Engineering Manager 8 -14-12 YAPLF a uskaaProcedures1C34- 261C34 -26 RWFP Procedure 8- 14- 12.doc • i F TO WELL Si 1988 PLF 3 -31 -12 NE R G Y Present Completion MGS C34-26 35' Cook Inlet, Alaska Water Depth: 73' MSL Leg 1, Conductor 3 Y API No.: 50- 733 - 2003 -00 " Spud: 1968 4. Tbg: 3 -1/2 ", 9.3 #, N80, EUE 8rd @ 10,683' Set 4 -15 -73 Surf Csg: 10 3/4 ", 40.5 Ib, J55. Otis Ball Valve 290' Set @ 1732'. Cmt'd w/ 1500 sx. GLM #1 2140' ALL GLM's GLM #2 4121' ARE DUMMY GLM #3 5650' GAS LIFT GLM #4 6912' VALVES GLM #5 7955' GLM #6 8756' GLM #7 9401' GLM #8 9835' Otis "X" Nipple 10673' Longstring 7 ", N80 BTC. Set @ 11,259'. EOT 10683' Cmt w/ 1200 sx. TOC @7900' 23# : Surface to 4711'. 26# : 4711 - 8646'. 29# : 8646 — 11,259'. Y4 ',,,;- "XO" Sliding Sleeve 9841' ...• Uni- Packer VII 9880' �' �Z1 ��� .fit GR -GS: 9919 -26' & 9932 -57' .. s •■•• HC -HD: 10,247 -256' & 10,284 -305' GLM #9 Dummy 10278' A "XO" Sliding Sleeve 10314' ? , =� ►�� . Uni - Packer VII 10331' i'"4' HD-HE: 10, 355 -65' SS @ 10,463' is Upside Down r �_ Iill HE -HF. 10,397 -453' GLM #10 Dummy 10428' Otis "XO" Sliding Sleeve 10463' ��� I•�� Uni - Packer VII 10481' HI-HK: 10,526-540' ' HK- HN(u):10,547 -644' GLM #11 Dummy 10610' ,. Otis "XO" Sliding Sleeve 10644 r •..�� I�� tea ', Uni - Packer VII 10662 ? :' 3.5" X Nipple (2.813" ID) 10673' '.1— H K -H N(I): 10,690 -10752 EOT @ 10,683' `^: HN -HR: 10,786 - 11000' ' . '. FISH 2' 34'2' Tbg w/ "Q" Nipple @ 11,024' (12 -4-76) PBTD: 11024' ,, �< � TD: 11282' _ 14 - ::��.., . ,• , 04h • • E TO PLF 8 -14 -12 NERGY PROPOSED Completion MGS C34 -26 ` % KB: 35' Cook Inlet, Alaska Water Depth: 73' MSL Leg 1, Conductor 3 � Tbg: 2 -3/8" 4.7# L80 8rd EUE. Set: API No.: 50- 733 - 2003 -00 Spud: 1968 4 4' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 300' �A 2 -3/8" Baker TE5 SSSV @ 304' 4' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 305' Surf Csg: 10 3/4 ", 40.5 lb, J55. ±303 Jts 2 -3/8" 4.7# L80 8rd EUE Set @ 1732'. Drift! w/ 1500 sx. 4' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 9895' 2 -3/8" X Nipple (1.875" ID) 9 Cr @ 9699' 4' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 9695' 1 Jt 2 -3/8" 4.7# L80 8rd EUE @ 9704' 7" TIW HM -1 L80 Retrievable Pkr @ 9735' 3 Jt 2 -3/8" 4.7# L80 8rd EUE @ 9739' 4' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 9832' 2 -3/8" XN Nipple (1.791" ID) 9 Cr @ 9699' 4' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 9832' Longstring 7 ", N80 BTC. Set @ 11,259'. 3 -W x 2 -3/8" TIW SBR Stabbed on @ 9846' Cmt w/ 1200 sx. TOC @7900' 23# : Surface to 4711'. MD ND PORT PSC Pao #1 2198 2350 12 942 1000 26# : 4711 - 8646'. #2 3786 3400 12 923 983 29# : 8646 — 11,259'. #3 4622 4300 12 903 934 #4 5821 5000 12 885 908 ' // # 6 6168 5500 12 863 886 #6 6768 6000 12 842 884 #7 7348 6500 14 815 845 #8 7930 7000 14 793 822 Tbg cut ±9846' #8 8517 7500 14 770 799 #10 9101 8000 14 747 775 Uni- Packer VII @ 9880' ►�� �� #11 9677 8500 14 ors . � GR -GS: 9919 -26' & 9932 -57' (SQZ'd) % _ , GLM #9 Dummy @ 10278 1•• HC HD: 10,247-256' & 10,284 -305' XO Sliding Sleeve @ 10314' (Shut) Uni - Packer VII @ 10331' ►�� �/ f HD - HE: 10,355 - 65' GLM #10 Dummy @ 10428' Iasi XO Sliding Sleeve @ 10463' (Shut) HE -HF: 10,397 - 453' ( SQZ'd) SS is Upside Down (1973) Uni- Packer VII @ 10,481' ►� �� J HI 10,526 GLM #11 Dummy @ 10610' I.. ^^ HK- HN(u): 10,547 -644' XO Sliding Sleeve @ 10644' (Shut) Uni- Packer VII @ 10662' DWI 3-'/° X Nipple (2.813" ID) @ 10673' HK HN (I): 10,690 � HN - HR: 10,786 - 11000' GC:XI FISH: 2' 3 Tbg w/ "Q" Nipple @ 11,024' (12 - 4 - 76) TDB: 11282' % / / / / /J /it /� I • e lk CAMERON XTO PLATFORM C Well 34 -26 Equipment CURRENT WH 8 -14 -12 ,-r ,,4) C, n Block Tree - with Integral and additional SSV Wing i , ;; @ - - ^ -- 3-1/8 API 5K Run with 2 -1/16 API 5K Wing '� ^ 4 I I Valves on wing use R -24 Ring Gaskets ..+q 0,4N 11 LL i •_ 9 Tubing Hanger has 3 "Type H BPV Profile (� ^'' "a P eum Ic I Y a Cssv r.. 1 , ...`7 , -W - 1 Lowermost Casing Head Type D Compact _ 11" 3K (#9 Clamp) Hub x 11 API 5K ( #10 Clamp) Hub Top R -53 MODIFIED Ring Gasket Bottom 8 Ring P , R -53 Rin Gasket To X > >, - f l .. Annulus Outlets are 2 -1/16 API 5K ,MA-‘' , , R -24 Ring Gasket: , 1...., =1 7 r ti ', \ _ 2 -1/16 API 5K ' R -24 Ring Gasket 4' 5" II 1 4 L 1 1 - - 2 " 1— 2 2" u; ib `' 2 -1/16 API 5K '" I :.'• -'! • R -24 Ring Gask • • f i e CAMERON XTO PLATFORM C Well 34 -28 PRODUCER REPLACEMENT EQUIPMENT 2012 Well currently has a Cameron Type D Compact Wellhead Existing 7" Casing will be cut to allow removal of the D Compact Housing. A new Casing Housing will be installed, the 7" tied back and a new Tubing Spool installed. We will also replace the Tubing Hanger, Adapter and Tree 'Eq uipment to be configured as shown p r Equipment to be configured as shown .9-,i 1 , n , 2- 1/16 5000 Wing HWO and Pneumatic Trees configured the same as existing J Actuated Wing valve with H2 Choke to be equipment currently on Wells per ti« .1 Shipped separate from run of Tree photographs , .-J- ;—_ - Replacemet _ c=- �i� �� -1 r _ 2-9/16 50I'ving 0 Tree P 4 `, • With 1 ` i_ °- 417 t-ui; 1I Replacement Tubing Head Adapter _-- I _ _n. 7 -1/16 x 2 -9/16 Stainless Adapter '°"" "'" " 1 ,— Replacement Tubing Hanger PN UNKNOWN __d_,_ 7 x 2 -7/8 EUE 8rd Stainless Replacement Tubing Spool - PN UNKNOWN CAMERON N 11 "5K x 7 -1/16 5K Top 1 'MO With (2) 2 -1/16 5K Valves „'-�� ,-I\ -= <;,,,: PN Unknown y l� \ T • , - y � -, Leave one of the Annulus Valves 2 i.: 1 ! 0 open ended to allow Line to be rigged 7 ;, NX Bottom Prep fly : -cam " ! , ;' r t\ r u Replacement Secondary rySe al ` • PN UNKNOWN n' Replacement Slips Replacement Casing Head E PN UNKNOWN PN UNKNOWN . _ i - _ ', \ ;' �` , R , i I 1. • 5/2312012 13 -625 BOP Schematic.xls XTO - ENERGY KB Elevation Date: 5/23/2012 "Rig Floor' I-1 F Flow line itydril 7 13 5/8" Sm 13 5/6" 6m Annular double ram preventer y I mamma-rim I ,..... a■ 13 515" 6m Cameron sly rr Pipe rams sfNSM • r • . • IN 13 61e" 61n Cameron ... emossom ' ice" Blind Rams III ' . • eeeeenys L __ 16 •#• �� 11 n n n nl Cir_EIGIDO 1 2 1116" Kill Line n n n II n S 118 "Choke Line 21/16" 3 1/8" 3 1/8" 5m 5m 5m Hydraulic Manual Manual Valve Valves valve 13 518 6m nser 135 Ils uw L y) Mud Cross with 3 1/8" ' outlets Page 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, April 18, 2013 3:28 PM To: 'Bridge, Alexander' Cc: Griffith, Scott; Haggard, Sandra Subject: RE: XTO Energy - MGS C34 -26 - Request for verbal approval to repair casing (PTD 168 -019) Alec, You have verbal approval to proceed with the RWO on C34 -26 as proposed in your attached sundry application. If the work scope changes notify the Commission immediately... Make sure you have a copy of the sundry and this email on the rig when you start operations on the well. Guy Schwartz Senior Petroleum Engineer AOGCC 907- 444 -3433 cell 907 - 793 -1226 office From: Bridge, Alexander [ma ito.AlexanderBridge u,xteener cy corn] Sent: Thursday, April 18, 2013 10:35 AM To: Schwartz, Guy L (DOA) Cc: Griffith, Scott; Haggard, Sandra Subject: XTO Energy - MGS C34 -26 - Request for verbal approval to repair casing Guy, Attached is a copy of XTO's Application for Sundry Approval to repair the 7" production casing in the MGS C34 -26. As we discussed previously, we noted pressure build -up on the 10 -3/4" casing x 7" casing annulus when we returned the well to production and began injecting lift gas after completing a workover (original workover: Sundry #312 -320). Please call me with any questions or concerns. A hard copy of the application will be mailed to your office. Regards, Alec Bridge Operations Engineer XTO Energy — Western Divison 303- 397 -3608 (0), 720 -244 -9083 (C) 1 ' OF 7j1 • • ,, THE STATE Alaska Oil and Gas *1 $ '� ° f Conservation Commission ALASKA _ GOVERNOR SEAN PARNELL 333 West Seventh Avenue O p. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 SCANNED MAR 18 2013 Sandra Haggard Regulatory Analyst 1(A-oily XTO Energy 9127 S Jamaica Street Englewood, CO 80112 Re: Middle Ground Shoal Field, E, F, and G Oil Pool, MGS C34 -26 Sundry Number: 313 -128 Dear Ms. Haggard: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster //'' Chair 7q-- DATED this �� day of March, 2013. Encl. SCANNED MAR 18 2013 T W1/4- R .S. Y' ¢ 4 i j4 0 ,s 31/� �3 . STATE OF ALASKA • .l i " . - 4. ' ALASKA OIL AND GAS CONSERVATION COMMISSION ' APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program 10 Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re - enter Susp. Well ❑ Stimulate ❑ Atter Casing ❑ Other. CT fCD 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. XTO ENERGY Exploratory ❑ Development Ei ' 168 -019 2t4 ;14-1 3 3. Address: 9127 S Jamaica Street Stratigraphic ❑ Service ❑ 6. API Number. Englewood, CO 80112 50 - 733 - 20093 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ Middle Ground Shoal C34 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 18756 z MGS E, F, G Oil Pools 4. 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) &D1$ • 11,282 9,908 - 11,024 9,692 NA ((QTY NA Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,732' 10 -3/4" 1,732' 1,642' 3,130 psi 1,580 psi Intermediate Production 11,259' 7" 11,259' 9,889' 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,919 - 11,000 • 8,720 - 9,672 3 -1/2" N -80 10,683 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 4 - Guiberson Uni- Packers, Otis SSSV please see attachment 12. Attachments: Description Summary of Proposal El - 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 - Service ❑ 14. Estimated Date for March 2013 15. Well Status after proposed work: Commencing Operations: Oil 0' Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sandra Haggard Email sandra haggardt'axtoenergy.com Printed Name Sandra Haggard Title Regulatory Analyst Signature , / � / Phone 303 - 397 -3672 Date 3/8/2013 /✓ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 3 ( 2 iii, CA' UY Plug Integrity ❑ BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ Other: s � C0) es.- ) RBDMS MAR 18 2O t, s( , / Spacing Exception Required? Yes ❑ No Subsequent Form Required: /6— L/ O q APPROVED BY Approved by: 7 COMMISSIONER THE COMMISSION Date: 3 - !g - /3 314{. /3 Submit Form and U°N1°0 e is / 2 Approved application is valid for 12 months from the date of ap oval. Attttaa hments in Duplicate /I \l, 1, ,6� • • E NERGY 1 March 8, 2013 AOGCC Alaska Oil and Gas Conservation Commission Attn: John Norman, Commissioner 333 W. 7 Ave., Suite 100 Anchorage, Alaska 99501 -3539 RE: Form 10 -403, request for Sundry Approval Objective: Clean out the 3 %A tubing string with coiled tubing prior to workover. Middle Ground Shoal #C34 -26 Water Injection Well Middle Ground Shoal Field, E, F & G Oil Pools Cook Inlet, Alaska API 50- 733 -20093 XTO Energy Inc. herby submits its Application for Sundry Approvals to pull tubing and repair well. Enclosed are the following attachments: 1. Form 10 -403 Application for Sundry Approval 2. Packers & SSSV MD (ft) and TVD (ft) Attachment • 3. Cover Page 4. Summary Page 5. Job Procedure 6. Wellbore Diagram If you require additional information, please contact me at (303) 397 -3672 Sincerely, s Sandra M. Haggard, Regulatory Analyst Copy To: Alec Bridge, Operations Engineer @ (303) 397 -3608 XTO Energy Inc. • P.O. Box 6501 • Englewood, CO 80155 • 9127 S. Jamaica St. • Englewood, CO 80112 • (303) 397 -3600 • Fax: (303) 397 -3899 An MaconMobil Subsidiary • • Form 10-403 Packers and SSSV MD (ft) and TVD (ft) MD TVD SSV 290 290 Pkr 1 9880 8680 ' Pkr 2 10331 9079 Pkr 3 10481 9213 Pkr 4 10662 9374 • • TO ENERGY • To: John Norman Guy Schwartz Victoria Ferguson CC: Scott Griffith Romeo Perez From: Alec Bridge RE: MGS C34 -26 Cook Inlet, Platform C Addition to previously approved workover program (Sundry #312 -320) The AOGCC previously approved XTO's Application for Sundry Approval (Sundry #312 -320) to workover the MGS C34 -26 and return the well to production. XTO is requesting approval to clean out the 3 -1/2" tubing string with coiled tubing prior to proceeding with the previously approved workover. If you require additional information, please contact me at 303 - 397 -3608. Sincerely, a ti /j& S 03/08/ 10/3 Alec Bridge Operations Engineer • • )( TO ENERGY XTO ENERGY MGS C34 -26 - EAST FLANK PRODUCER COOK INLET, ALASKA COIL TUBING CLEAN OUT PROCEDURE WELL DATA SURFACE CASING: 10 -3/4" 40.5# J55 BTC. Set @ 1,732'. Cmt w/1,550 sx. LONGSTRING CASING: 7" 23, 26 & 29# N80. Set @ 11,259'. Cmt w /1,200 sx. TOC @ 7900'. Surface — 4,711': 23# 4,711' — 8,646': 26# 8,646' — 11,259': 29# TUBING: 3 -1/2" 9.3# N80 8rd EUE @ 10,683' PACKERS: 4 ea 7" Guiberson Uni- Packer VII @ 9,880', 10,331', 10,481' & 10,662' Packers set in 1973 PERFORATIONS: GR -GS: 9,919' — 26' & 9,932' — 57' HC -HD: 10,247' — 56' & 10,284' — 305' HD -HE: 10,355' — 65' HE -HF: 10,397' — 453' HI -HK: 10,526' — 40' HK -HN: 10,547' — 644' & 10,690' — 752' HN -HR: 10,786' — 11,000' FISH: 2' 3 -1/2" tbg w /Q- Nipple @ 11,024' PBTD: 11,024' BHST: 170° F BHP: ±4,500 psi (SI WHP = 500 psi) SMALLEST ID: 2.813" ID X Nipple @ 10,673' PRESENT STATUS: SI w /500 psi WHP & 350 psi Csg Press. OBJECTIVE: Clean out 3 -1/2" tbg prior to performing RWTP workover • • NOTES: • This job will be performed prior to the originally planned workover to return this well to production (Sundry #312 -320, AFE #1200385). After performing the coil tubing clean out procedure, we will proceed with the return well to production workover as planned. • Barney made slickline run on 02/17/2013 to 2,148' w/2.70" drift tool and could not go any deeper. EQUIPMENT & MATERIALS REQUIRED: • 1.75" CTU • 2 -1/2" motor & tapered mill • 1 -3/4" Roto -Jet washing nozzle • Filter Skid w/2 — 10 micron filters • 2 gpt FRW -16A friction reducer • 10 bbl gel pill (2# /bbl FloZan + 3 gal Greencide) • 10.3 ppg CaC1 fluid PROCEDURE: 1. MIRU Baker Hughes 1.75" CTU, riser, BOPE, and injector head. Install pressure gauges on CT, CT x 3 -1/2" tubing annulus, and 3 -1/2" tubing x 7" casing annulus. Notify AOGCC 24 hours prior to BOPE test. MU motor and mill on EOT. Caliper all tools before RIH (smallest ID = 2.813", X Profile in sliding sleeves and X Nipple at 10,673'). Pressure test treating lines to 5,000 psig. Maximum treating pressure is 4,000 psig. 2. Hold pre job safety meeting. 3. Open WH for circulation. RIH with CT at 60 FPM while pumping FIW at 1 BPM. Slow RIH rate as necessary when encountering fill (note: SL encountered fill @ 2,148') and passing gas lift mandrels (see attached WBD). Continue RIH and clean out to PBTD at 11,024' (at a minimum, clean out to the top packer at 9,880'). 4. Circulate a 10 bbl gel pill followed by 100 bbls FIW. Load 3 -1/2" tubing with 10.3 ppg CaC1 fluid (this is the fluid that will be used for the workover). 5. Open CT annulus. POOH with coil tubing @ 100 FPM. Bleed off pressure. RD CTU. 6. Proceed with RWTP procedure (Sundry #312 -320, Approved 08/29/2012). i • ; (TO WELL SI 1988 PLF 3 -31 -12 ENERGY Present Completion MGS C34 -26 r KB: 35' Cook Inlet, Alaska Water Depth: 73' MSL Leg 1, Conductor 3 API No.: 50- 733 - 2003 -00 Spud: 1968 Tbg: 3 -1/2 ", 9.3 #, N80, EUE 8rd @ 10,683' /,. Set 4 -15 -73 Surf Csg: 10 3/4 ", 40.5 Ib, J55. Otis Ball Valve 290' Set @ 1732'. Cmt'd w/ 1500 sx. GLM #1 2140' ALL GLM's GLM #2 4121' ARE DUMMY GLM #3 5650' GAS LIFT GLM #4 6912' VALVES GLM #5 7955' GLM #6 8756' GLM #7 9401' GLM #8 9835' Otis "X" Nipple 10673' Longstring 7 ", N80 BTC. Set @ 11,259'. EOT 10683' Cmt w/ 1200 sx. TOC @7900' 23# : Surface to 4711'. 26# : 4711 - 8646'. 29# : 8646 – 11,259'. •••• "XO" Sliding Sleeve 9841' Uni- Packer VII 9880' GR -GS: 9919 -26' & 9932 -57' ■ ■ ■■ _ HC -HD: 10,247 -256' & 10,284 -305' GLM #9 Dummy 10278' V "XO" Sliding Sleeve 10314' � � �� U ni- Packer VII 10331' HD-HE: 10, 355 -65' SS @ 10,463' is Upside Down i I I I HE -HF: 10,397 -453' GLM #10 Dummy 10428 Otis "XO" Sliding Sleeve 10463' �� r Uni-Packer VII 10481' HI-HK: 10,526-540' •••• - HK-HN(u): 10,547-644' GLM #11 Dummy 10610' Otis "XO" Sliding Sleeve 10644 Uni- Packer VII 10662' 3.5" X Nipple (2.813" ID) 10673' - HK- HN(I): 10,690- 10752' EOT @ 10,683' HN -HR: 10,786-11000' '11110 FISH: 2' 3 Tbg w/ "Q" Nipple @ 11,024' (12 - 4 - 76) PBTD: 11024' /, TD: 11282' % Rev J srcl approve' d ,Z -32 v • I -�Svvid ry 3 woe dc-' c to /s /1Z� P mt s - c s l� - lO. P D /G,0 -o/ 9 1 s � ;f IV`ERGY l/L 0/5ii XTO ENERGY INC. MGS C34 -26 COOK INLET, ALASKA — EAST FLANK Return Well to Production Procedure WELL DATA: SURFACE CASING: 10 - 3 /4" 40.5# J55 BTC. Set @ 1732'. Cmt w/ 1550 sk. LONGSTRING CASING: 7" 23, 26 & 29# N80. Set @ 11,259'. Cmt w/ 1200 sk. TOC @ 7900' Surface — 4711': 23# 4711— 8646': 26# 8646 — 11,259': 29# TUBING: 3-Y2" 9.3# N80 8rd EUE @ 10,683'. PACKERS: 4 ea 7" Guiberson Uni- Packer VII @ 9880', 10,331', 10,481' & 10,662'. Pkrs set in 1973. PERFORATIONS: GR -GS: 9919 — 26' & 9932 - 57' HC -HD: 10,247 — 56' & 10,284 — 305' HD -HE: 10,355 — 65' HE -HF: 10,397 — 453' HI-HK: 10,526 — 40' HK -HN: 10,547 — 644' & 10,690 — 752' FIN-HR: 10,786 — 11,000' FISH: 2' 3 -1/2" tbg w/ Q Nipple @ 11,024' PBTD: 11,024' SCANNED APR 08 Z 013 BHST: 170 Deg F BHP: ±4500 psi (SI WHP = 500 psi) SMALLEST ID: 2.813" ID X Nipple @ 10,673' PRESENT STATUS: SI w/ 500 psi WHP & 350 psi Csg Press. OBJECTIVE: Replace 3 -1/2" GL string w/ 2 -3/8 ". • AFE # 1200385 Sundry #312 -320 • Prior to Workover, Slickline will run gauge ring to determine the condition of the tbg ID for WL jet cut. If tbg is scaled up, Coil tbg will be used to clean -out the tbg ID. • The entire D Compact Wellhead will be replaced which will require cutting & replacing the top 150' of 7" casing. • Need 11" x 13 -5/8" clamp adapter for BOP. 10 -5 -12 C:\ Users\ vlferguson \AppData\Local\Microsoft \Windows \Temporary Internet Files\ Content.Outlook \GTCWFQ55\C34 -26 RWTP Procedure 10-5 - 12.docx • • 2 Equipment: • RHCP Plug (Pollard) Installed in 2 -3/8" XN. • 4' drop bar w/ ball (Pollard) Materials Rqd: • 5 gal WC1447WR Corrosion Inhibitor (Nalco) • 5 gal EC6112A Biocide (Nalco) • 100 bbl Gel Pill (2 #/bbl FloZan + 3 gal Greencide) (Provided by MI) • 67,000 lbs CaC12 (112 lbs/bbl FIW to build 10.3 ppg) Maintain MW from last well. PROCEDURE: 1. Bleed -off well to header. 2. RU Slickline & lubricator. RIH w/ 2.70" gauge ring to X nipple @ 10,673'. Reduce gauge OD if the 2.70" will not get DH. RIH w/ pulling tool to GLM #8 @ 9835'. Latch & POOH the dummy valve. RD lubricator. 3. MIRU Derrick. Mix up 400 bbl 10.3 ppg CaCl2 mud (use from last WO). Circ to kill well through GLM #8 @ 9835'. Take wellbore fluids to disposal well and recover /maintain the 10.3 ppg Salt mud. 4. SD & monitor well for 60 minutes to make sure well is dead. 5. Notify the AOGCC 48 hrs prior to BOP test. Set BPV. ND WH. Set 11" 5K x 13 -5/8" clamp adapter. NU riser & BOP's. Pull BPV's & set 2 -way check valve. Ensure BOP has 3 -1/2" VPR pipe rams. Press test BOP's to 250 psi & 5000 psi. Send D Compact WH to OS for scrap. 6. MI 11,400' 3 -1/2" 15.5# S135 drill pipe & 6 ea 4 -3/4" DC's. 7. MIRU Pollard WL. RIH w/ Radial Torch cutter & CCL. Pull the tbg in tension. Cut the tbg ±5' below the SS @ 9841'. POOH. Observe the quality of the cut tbg as per Step #24 if stub will require a dressing. Leave WL on board for Step #20. 8. RU slips & tongs for 3 -1/2" tbg. POOH & LD 3 -1/2" tbg w/ 8 GLM's while checking for NORM. Send tbg & GLM's to onshore to be sold for scrap. Casing Cut for Csg Spool Removal: 9. MI 4 jts 7" 29# L80 BTC. 10. RIH w/ HOWCO 7" 23# RBP & set @ 500'. Close pipe rams & press test to 1000 psi. POOH. Drop 500 lbs (20') of sand on top of RBP. 10 -5 -12 C:\ Users\ vlferguson \AppData\Local\Microsoft \Windows \Temporary Internet Files\ Content.Outlook \GTCWFQ55\C34 -26 RWTP Procedure 10-5 - 12.docx • • 3 11. MU 7" casing cutter on DP. RIH & cut the 7" csg ±20' below the WH assembly. Circ out any gas. POOH & LD cutter. 12. ND BOP's. 13. Remove the bottom clamp from bottom of D Compact WH. LD WH w/ casing hanger & the 20' 7" casing stub. 14. NU the new Cameron 11" 3K x 13 -5/8" 5K casing head. Weld landing hub to 10 -3/4" csg. c 15. RIH wl 4 -1/4" x 7 -3/8" TAM Inflatable Pkr as per Attached TAM Running Procedure to ±100'. !� Inflate & release from the pkr. POOH w/ DP. 16. NU 13 -5/8" 5K flange with connection for test port. RU line. 17. Using a chart recorder, press test the weld & new clamp on the bottom of the new Casing Head to 2000 psi for 30 min against the inflatable pkr. Z 18. ND the 13 -5/8" flange. RIH & deflate the pkr. POOH w/ ph. 19. Notify the AOGCC 48 hrs prior to BOP test. NU BOP's w/ 7" casing rams. Press test BOP's to 250 psi & 5000 psi. 20. RIH w/ 5 -3/4" ITCO Spear w/ 2.0" ID and engage the top of 7" & PU 5000# over string wt. RU Pollard WL. RIH w/ string shot & CCL. Apply recommended torque to 7 ". Fire string shot in collar between 100 -150'. Backoff casing at collar. POOH & LD ±3 jts csg. 21. RU Casing Crew. PU Guided Skirt jt followed w/ 3 reg jts of 7" 26# L80 BTC -M. Slip skirt over the collar from previous step & MU threads. Screw on 7" swage w/ 1502 2" connection. RU mud pump and press test the new 7" connection against the RBP to 2000 psi for 30 min. Bleed -off press. RD BOP's. Hang off 7" on slips in WH, make cut and install new Cameron Tubing Spool. 22. Notify the AOGCC 48 hrs prior to BOP test. NU BOP's with VPR's for 2 -3/8" & 3 -1/2 ". Set WH test plug in tbg spool. Press test BOP's to 250 psi & 5000 psi. 23. RIH and wash off sand & retrieve the 7" RBP @ 500'. 24. Based upon results from Step #7 - RIH w/ dress -off mill to dress off top of the 3 -1/2" tbg stub @ ±9846'. BHA to consist of mill, casing scraper for 29# & MAGTRAP. LIGHTLY tag up on tbg stub @ 9846'. Dress -off tbg stub as per instructed. Reverse circ 20 bbl gel sweep. Make a casing scraper run as minimum if tbg stub dress -off is not necessary. 25. RIH w/ Howco 7" RTTS packer to 9735'. CCL has collars @ 9719' & 9763'. Est circ w/ FIW. Set ph. Perform MIT on 7" x DP annulus to 2000 psi. Monitor press for 30 min. POOH & LD DP. 26. MI 10,200' 2 -3/8" 4.7# L80 8rd EUE tbg (inc13% excess). 10 -5 -12 C:\ Users\ vlferguson \AppData\Local\Microsoft \Windows \Temporary Internet Files\ Content.Outlook \GTCWFQ55\C34 -26 RWTP Procedure 10-5 - 12.docx III • 4 I 27. RIH w/ TIW 7" HM -1 Retrievable Packer on 2 -3/8" 4.7# L80 8rd EUE tbg and land as follows: Item Length, ft Top Bottom 2 -3/8" 4.7# L80 8rd EUE 300 0 300 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 300 304 2 -3/8" Baker TE5 SSSV 1 304 305 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 305 309 2 -3/8" 4.7# L80 8rd EUE 9,386 309 9,695 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 9,695 9,699 2 -3/8" X Nipple (1.875" ID) 9 Cr 1 9,699 9,700 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 9,700 9,704 1 jt 2 -3/8" 4.7# L80 8rd EUE 31 9,704 9,735 7" TIW HM -1 Retrievable Packer L80 4 9,735 9,739 3 Jt 2 -3/8" 4.7# L80 8rd EUE 93 9,739 9,832 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE _ 4 9,832 9,836 2 -3/8" XN Nipple (1.791" ID) 9 Cr 1 9,836 9,837 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 3 9,837 9,840 3 -1/2" x 2 -3/8" TIW SBR Stabbed on @ 9846' 6 9,840 9,846 Gas Lift Design GLM MD TVD PORT PSC PSO #1 2198 2050 12 942 1000 #2 3786 3400 12 923 963 #3 4822 4300 12 903 934 #4 5621 5000 12 885 908 #5 6192 5500 12 863 886 #6 6768 6000 12 842 864 #7 7348 6500 14 815 845 #8 7930 7000 14 793 822 #9 8517 7500 14 770 799 #10 9101 8000 14 747 775 #11 9677 8500 14 Orifice Each GLM to have a 4' Pup Jt on top & 6' Pup Jt on bottom. 28. PU landing jt & stab 3 -1/2" SBR onto 3 -1/2" tbg stub at 9846'. 29. Pull SBR off seat. Mix up 20 bbl biocide /pkr fluid pill to contain 5 gal Nalco EC1447WR + 5 gal EC6112A in 20 bbl FIW. Circ pill down tbg w/ FIW. Under - displace pill by 10 bbl inside the tbg. Set down SBR. 30. Space out & make up and land new Tbg Hanger. Run in lock screws to energize hanger seal. 31. RU Slick line & press test lubricator to 4000 psi. RIH w/ 1.5" tool to 8200' to verify the SBR is stabbed onto 3 -1/2" tbg sub @ 9846'. 10 -5 -12 C:\ Users \vlferguson\AppData \Local \Microsoft \Windows \Temporary Internet Files\ Content.Outlook \GTCWFQ55\C34 -26 RWTP Procedure 10-5 - 12.docx • • 5 32. RIH w/ PXN plug & set in XN nipple @ 9836'. Press test tbg to 1,000 psi for 15 min. Monitor falloff. Cont to press up to ±3,500 psi to set ph. Hold 4,000 psi on the tbg for 15 min. POOH w/ SL. 33. Set BPV. ND BOP's. NU WH w/ new tbg head adapter. Pull BPV. Set 2 -way check. Test WH to 5,000 psi. Pull 2 -way check. 34. RU SL. RIH & pull the PXN plug. RD SL. PWO gas lift. Paul Figel Engineering Manager 10 -5 -12 C:\ Users \vlferguson\AppData\Lo al\Microsoft \Windows \Temporary Internet Files\ Content.Outlook \GTCWFQ55\C34 -26 RWTP Procedure 10-5 - 12.docx • • EirairE (1[1.' ALAS ER\ SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION CONS COMMISSION ANCHORAGE, ALASKA 99501 -3539 i1 PHONE (907) 279 -1433 Maria Perez Regulatory Analyst 666 - XTO Energy, Inc. j 200 N. Loraine, Suite 800 'v. � 0 AUG 0 : Midland, TX 79701 Re: Middle Ground Shoal Field, E, F, 8s G Oil Pool, MGS #C34 -26 Sundry Number: 312 -320 Dear Ms. Perez: 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. Commissioner DATED this Z" of August, 2012. Encl. E NERGY a subsidiary of ExxonMobil RECEIVED August 16, 2012 AUG .1 7 i; i2 Alaska Oil and Gas Conservation Commission AOGCC Attn: John Norman, Commissioner 333 W. 7 Ave., Suite 100 Anchorage, Alaska 99501 -3539 Re: Form 10 -403, request for sundry approval Objective: Pull tbg, replace wellhead, and run new gas lift string. Middle Ground Shoal #C34 -26 Production Well Middle Ground Shoal Field, E, F, & G Oil Pool Cook Inlet, Alaska API 50- 733 - 20093 -00 -00 XTO Energy Inc. hereby submits its Application for Sundry Approval to pull tbg, replace wellhead, and run gas lift string. Enclosed are the following attachments: 1. Form 10 -403 Application for Sundry Approval. 2. Cover Page 3. Summary Page. 4. Production Plot 5. Sub Surface Safety Valve Report 6. Deviation Survey. 7. Job Procedure. 8. Current Wellbore Diagram. 9. Proposed Wellbore Diagram. 10. Current Wellhead Schematic 11. Replacement Wellhead. 12. BOP Schematic. If you required additional information, please contact Paul Figel, Engineering Manager at A/C 432 -620- 6743. Sincerely, Maria L. Perez, Regulatory Analyst Tel. No. A/C 432 - 620 -4325 Copy to: Paul Figel, Engineering Manager 200 N. LORAINE, SUITE 800, MIDLAND, TEXAS 79701 ' ' " 1AL 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1 ‘ �' 20 AAC 25.280 L 1. Type of Request: Abandon El Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ r i Change Approved Program El Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ik U Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well 0 Stimulate ❑ Alter Casing Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: XTO Energy Inc. Development 0 • Exploratory ❑ 168 -019 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 200 N. Loraine, Suite 800, Midland, Texas 79701 50- 733 - 20093 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: E I property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 Middle Ground Shoal C34 -26 • Atli; f7 ; 7 9. Property Designation (Lease Number): 10. Field / Pool(s): 1�2 ADL 18756 " MGS E, F, G • 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): 11,282 9,908 11024 9692 NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1732 10 3/4 1732 1642 3130 1580 Intermediate Production 11259 7 11259 9889 6340 3830 1 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9919 -11000 8720 -9672 3 -1/2" N -80 10683 Packers and SSSV Type: 4- Guiberson Uni -Pkr 7, Otis SSSV Packers and SSSV MD (ft) and TVD (ft): See Attached 12. Attachments: Description Summary of Proposal is 13. Well Class after proposed work: Detailed Operations Program 13 BOP Sketch El Exploratory ❑ Development El Service ❑ 14. Estimated Date for Nov. 2012 15. Well Status after proposed work: Commencing Operations: Oil El • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Figel, Engr 432 - 620 -6743 Printed Name Maria Perez Title Regulatory Analyst Signature / �,n Phone 432- 620 -4325 Date 8/16/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: j/a • 3 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 7 f = S3 () /7 - to . -7 C' e t /.2 -L- Subsequent Form Required: r0 _y �G, � . J f 1 / AP PROVED BY / -( r Approved by: ,' C THE COMMISSION Date: i,�,� �1pg'�+A , F , P z 7 bmt n Duplicate M,/ Z' O z L • Form 10 -403 Packers and SSSV MD (ft) and TVD (ft) MD TVD SSV 290 290 Pkr 1 9880 8680 Pkr 2 10331 9079 Pkr 3 10481 9213 Pkr 4 10662 9374 • • /T ERGY August 15, 2012 To: John Norman Guy Schwartz Victoria Ferguson Cc: Scott Griffith Scott Landon From: Paul Figel Subject: Workover for MGS C34 -26 (168 -019): Return Shut -in Well to Production. Objective: The objective for the workover proposed for the C34 -26, located on Platform C, Cook Inlet is to replace the current 3 -1/2" gas lift string with 2 -3/8" tubing and return the well to production. The . well currently has 4 Guiberson retrievable packers that were installed in 1973 to isolate the various zones. Past experience has shown that these Guiberson packers require milling out as they will not release. Therefore, for economic purposes, the 3 -1/2" tubing will be cut above the v. existing top packer and will be conjoined with a PBR below a new packer. This well is currently equipped with an outdated product (Type D Uni- Compact Head) that Cameron no longer supports nor has adapter parts to allow for a new tubing hanger to be installed. Therefore, the entire existing wellhead will be removed and replaced with a . conventional multi - compartment wellhead. This will be done as outlined in the procedure requiring that the 7" Longstring be cut below the deck to allow the removal of the lowermost casing head section. Approximately 150' of the 7" casing will be replaced and brought back to surface and hung off in a new casing head with slips. This will allow a new tubing spool to be installed. Well History: This well was drilled in the East Flank in 1968 and completed in the 13 separate Hemlock intervals from the GR to HR. The well IP'd 1970 BOPD, 24 BW & 689 MCF. The C34 -26 was offset to injectors C -Line (4000 BWIPD) and C23 -26 (3500 BWIPD) as of 1969. A production log was run in July 1971 as the water jumped from 125 to 500 BWPD and oil fell 1500 to 800 BOPD. The survey showed 8 of the 13 intervals contributed less than 50 BPD. Therefore, in Dec 1971 an acid job was pumped which, according to the 1972 production log, had minor inflow effects but verified that the HE -HF, HI -HK & HK -HN were contributing +90% of the water. The well was recompleted in 1973 with 4 isolation packers and sliding sleeves to selectively produce: 1: GR -HD (open), 2: HD -HF (closed), 3: HI -HN(u) (open), 4: HI -HN(1) (open), & 5: HN -HR (open), however, the sliding sleeve for the HD -HF was installed upside down was closed when thought to be open from 1973-'76. This was discovered in 1976 when slickline tried to "close" the SS but actually opened the sleeve causing the well to kick and flowed 1600 BPD @ 1700 psi WHP. The top 3 SS were closed #1 (GR -HD), #2 (HD -HF) and #3 (HI- HN(u)) and the • 2 well tested 152 BOPD & 102 BWPD from the HK -HN(1) & HN -HR. In Dec '76, these zones were reperforated and gained 60 BOPD without any water. The C34 -26 lost the injection support of the C -line well in 1981, 5000 to 1800 BWIPD, and then again in 1984 when the C23 -26 had the HC -HN cement squeezed dropping support to 300 BWIPD. See attached Production Plot. The last treatment was done in 1985 with a small 2000 gal xylene -acid job performed with coil tubing which had minimal effects. The well was shut -in in 1988 due to economics only making 9 BOPD & 81 BWPD. The cumulative production is 3.3MBO. The anticipated date for operations start up is November 2012. Please contact me at 432 -620- 6743 with any questions or concerns. Sincerely, Paul Figel Engineering Manager • • WORKOVER SUMMARY for C34 -26 Scope of work: Cut the 3 -1/2" production tbg below the top sliding sleeve @ 9841'. POOH with the current 3 -1/2" gas lift string and replace with a 2 -3/8" gas lift string that will stab onto the tbg stub @ ±9846' with a PBR assembly. The current lowermost casing head section will be replaced with a new conventional casing head that will allow for the installation of a new tubing spool and tubing hanger. Current Well Status: Shut -in 1988. Last prod was 9 BO & 81 BW. SI WHP = 500 psi. Well Info: See Attached Procedure & TVD Survey. SSSV test — see attachment. MASP: Prod is 90% Water Cut based on last prod @ 9 BO & 81 BW. 8.4 ppg FIW = 0.437 psi /ft 34 API = 0.3702 psi /ft. Mid Perf TVD: 9192' Top Perf TVD: 8715' BHP = [(0.1)(0.3702 psi /ft)(9192') + (0.9)(0.437 psi /ft)(9192')] + 500 psi = 4455 psi Phyd = (0.1)(0.3702 psi /ft)(8715') + (0.9)(0.437 psi /ft)(8715') = 3751 psi MASP = 4455 — 3751 = 704 psi Kill Weight: 4455 psi = (0.052) (8715' Top Perf TVD) (x, ppg) x = 9.8 ppg + 0.5 ppg = 10.3 ppg mud Mud Recipe will be 8.4 ppg FIW + 112 lbs/bbl CaC12 MIT Info: NA as a producer BOP Ram Configuration: VPR for 2 -3/8" to 3 -1/2 ". Schematic Attached. Workover Rig: XTO derrick is a permanent rig on Platform C. Contact Info: • Operations Engineer: Paul Figel, XTO Energy, 432 - 620 -6743, paul figel @xtoenergy.com • Superintendent: Scott Griffith, XTO Energy, 907 - 776 - 2506, scott_griffith@xtoenergy.com <Arrbiguous> 10000 NIDELE GROUZ SI M_ '81 Offset lnj C -Line SI 5000 1 rt` i rThlrilw I' a = '73 Reperf + Set Iso Pkrs = (SS HD -HF Closed) Z x '1 '84 Offset Inj C23 -26 1000 =1 = SQZ HC -HN +Set ISO Pkr • a> r) 500 A , 1 i I _, 1 i� 1 , 'i pu. i , 100 , �v, 72 z 50 a = Oil, 1 il , Q Z.3 a rt 10 V\ELL: MGS (E) C23-26 (INJ), MGS (E) C34 -26, MGS C-LINE (INJX3) CD F. o CD V1tr i P 7 LI 5 - CD Gas / W •---.- CD Wrinj • CD InjPress + Test_BOPD_Alasia 0 Test_B'APD Alma A Test MCFPD Alaska 1968 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 Date Cum Oil 3300148.000 Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: XTO Energy Submitted By: Barney Phillips Date: 5/20/2012 Operator Rep: Barney Phillips Field/Unit/Pad: MGS XTO C Platform AOGCC Rep: Matt Herrera Separator psi: LPS 68/68 HPS Well Data Pilots SSV SSSV Retest/SI Date Well Type Well Pressures Gas Lift Waiver Well Permit Separ Set L/P Test Test Test Date Passed Retest Oil, WAG, GINJ, Inner Outer Tubing Yes/No Yes/No Number Number PSI PSI Trip Code Code Code Or Date Shut In GAS, CYCLE, sI PSI PSI PSI C12 -23 1900200 68 37 38 P P P OIL 100 Yes No C13 -13LN 2022130 1/1/2006 SI No No C13 -23 1880990 68 37 38 P P P OIL 95 Yes No 0 C13A -23 1901060 P P OIL 90 Yes No C21 -23 1890870 P P OIL 95 Yes No C21 -26 1890040 P P OIL 100 Yes No C21A -23 1910440 P P OIL 95 Yes No C22 -23 1880160 12/19/2004 SI Yes No C22 -26RD 1760650 5/5/2012 SI Yes No C22A -26LIN 2041820 P P OIL 85 Yes No C24 -26RD 1790620 4/1/1992 SI Yes No C31 -26RD 2041400 P P OIL 90 Yes No C32 -23LW 2020340 P P OIL 75 Yes No C34 -26 1680190 11/1/1988 SI Yes No C42 -23 1780240_ P P OIL 95 Yes No C43 -14 1881320 P P OIL 3425 No No Wells: 11 Components: 24 Failure 0 Failure Rate: 0.00% ❑ 9.v III Remarks: PLB 01/26/11 Page 1 of 1 SVS MGS C Platform 5- 20- 12.xls . , 0 0 11111111 , Vaints , L C Platform, Well C34-26 UsITEQ Alaska State Plane Coordinates Measured Angle Azimuth TVD-RKB TVD X Y N / -S E / -W DLS Vert. Sec SVY# Depth ' deg 1 deg ft Subsea ft ft ft ft deg/100 ft ft Tie-In 0.00 0.00 0.00 0.00 -105.00 231364.82, 2474232.49 0.00 0.00 0.00 0.00 1 75.00 0.08 209.00 75.00 -30.00 231364.79 2474232.44 -0.05 -0.03 0.11 0.01 2 100.00 0.17 314.00 100.00, -5.00 231364.76 2474232.45 -0.04 -0.06 0.82 0.05 3 125.00 0.25 40.00 125.001 20.00 231364.77 2474232.52 0.03 -0.05 1.17 0.06 4 150.00 1 0.08 I 41.00 150.00 45.00 231364.8212474232.57 0.09 -0.01 0.68 0.03 5 175.00 0.17 45.00 175.00 70.00 231364.85 2474232.61 0.13 0.03 0.36 0.01 6 200.00 0.17 41.00 200.00 95.00 2474232.67 0.18 0.08 0.05 -0.02 7 225.00, 0.08 21.00 225.00 120.00 231364.94 2474232.71 0.23 0.11 0.39 -0.04 8 250.00 0.08, 319.00] 250.00 145.00 231364.93 2474232.74 0.25 0.11 0.33 -0.02 9 275.00 0.25 309.001 275.00 170.00 231364.88 2474232.79 030005 0.69 0.05 10 300.00 0.33 259.00 300.00, 195.00 231364.77 2474232.81 0.32 -0.06 1.02 0.16 11 325.00 0.42 218.00 325.001 220.00 231364.64 2474232.73 0.24 -0.19 1.10 0.25 12 350.00 0.42 230.00 350.00 245.00 231364.51 2474232.68 0.11 -0.31 0.35 0.33 Tie-In 363.00 0.33 248.00 363.00 258.00 231364.44, 1 2474232.56 0.06 -0.38 1.13 -0.12 1 1 400.00 0.75 23.00 400.00 295.00 231364.4412474232.74 0.24 -0.39 2.73 -0.30 2 500.00 3.50 66.00 499.92 I 394.92 231367.52 2474234.51 2.09 2.66 3.00 -1.68 3 600.00 5.25 86.00 599.63 494.63 231374.91 2474235.91 3.65 10.01 2.30 -2.16 4 700.00 7.00 131.00, 699.11 594.11 231383.99 2474232.02 -0.03 19.18 4.95 2.81 5 800.00 7.25 154.00 798.36 693.36 231391.14 2474222.18 -9.70 26.55 2.84 13.44 6 900.00 10.501 174.00 897.17, 792.17 231394.52 2474207.36 -24.44 30.27 4.44 28.56 7 1000.00 14.751 174.00 994.73 889.73 231396.31 2474185.58 -46.18 32.55 4.25 50.40 8 1100.00 18.00 175.00 1090.66 985.66 231398.35 2474157.47 -74.24 35.23 3.26 78.55 9 1200.00 22.00 175.00 1184.61 1079.61 231400.5512474123.35 -108.30 38.21 4.00 112.69 10 1300.00 26.00 175.00 1275.95 1170.95 231403.17' 2474082.77 -148.81 41.75 4.00 153.29 11 1400.00 30.50, 175.001 1364.02 1259.02 231406.23 2474035.55 -195.95 45.88 4.50 200.53 12 1500.00 32.00 174.00 1449.50 1344.50 231410.03 2473983.81 -247.59 50.86 1.59 252.34 13 1600.00 32.00 174.00 1534.31 1429.31 231414.37 -300.29 56.40 0.00 305.29 14 1700.00, 31.75 174.00 1619.23 1514.23 231418.69 2473878.37 -352.80 61.92j 0.25 358.05 15 1800.001 30.50; 174.00 1704.83 1599.83 231422.93 2473826.86 -404.21 67.32 1.25 409.70 16 1900.00 30.50 172.00 1791.00 1686.00 231427.96 2473776.36 -454.58 73.50 1.02 460.43 17 2000.00 31.50 173.00 1876.71 1771.71 , 231433.52 L 2473725.16 -505.64 80.22 1.12 511.93 18 2100.00 31.25 173.00 1962.09 1857.091231438.6812473673.36 -557.32 86.57 0.25 563.98 19 2200.00 32.00 172.00, 2047.24 1942.24 231444.35 2473621.23 -609.30 93.41 0.92 616.41 1 20 2300.00 32.00 170.00 2132.05 2027.05 231451.44 2473568.72 -661.63 101.70 1.06 669.39 21 2400.00 32.25 172.00 2216.74 2111.741231458.5612473516.03 -714.15 110.02 1.09 722.55 22 2500.00 32.75 172.00 2301.08 2196.08 231464.83 2473462.67 -767.36 117.50 0.50 776.28 23 2600.001 33.50L 171.00 2384.83 2279.83 231471.68 2473408.46 -821.40' 125.58 0.93 830.93 24 2700.00 34.00 171.00 2467.97 2362.97 231479.12 2473353.40 -876.27 134.27 0.50 886.48 25 2800.00 34.50 172.00 2550.63 2445.63 231486.16 2473297.57 -931.94 142.58 0.75 942.76 26 2900.00 32.25 173.00 2634.14 2529.141 2473242.88 -986.47 149.78 2.32 997.76 27 3000.00 29.75 183.00 2719.90 2614.90 231492.90 2473191.55 -1037.77 151.73 5.72 1048.80 Tie-In 3133.00 28.75 180.00 2835.95 2730.95 231489.70 -4 2473126.67 -1102.71 150.00 1.33 1091.32 1 I 3269.00 29.25 179.00 2954.90 2849.90 231488.78 2473060.74 -1168.64 150.58 0.51 1157.08 2 3424.001 30.25 177.00 3089.471 2984.47 231489.73 2472983.85 -1245.50 153.29 0.91 1233.62 3 3580.00 31.25 177.00. 3223.54 3118.54 231492.10 2472904.12 -1325.15 157.46 0.64 1312.87 4 3731.00 30.25 178.00 3353.31 3248.31 231493.72 2472826.94 -1402.28 160.84 0.74 1389.64 5 3888.00 30.25 178.00 3488.93 3383.93 231494.68 -1481.32 163.60 0.00 1468.36 6 4111.00' 30.50 178.00 3681.32 3576.32 231496.05 2472635.10 -1594.02 167.54 0.11 1580.59 7 4204.00 30.25 175.00 3761.56 3656.56 231497.85 2472588.i3 170.40 1.65 1627.25 8 4424.00 29.50 177.00 3952.33 3847.33 231503.02 2472478.68 -1750.24 178.07 0.57 1735.87 9 4579.00 29.251 178.00 4087.40 3982.40 231504.61 2472402.67 -182610 181.39 0.36 1811.47 10 4797.00 28.75 179.00 4278.07 4173.07 231504.98 2472296.99 -1931.85 184.16 0.32 1916.75 11 i 5016.00 28.25 181.00 4470.53 4365.53 231502.62 2472192.53 -2036.33 184.17 0.49 2021.03 12 5112.001 28.00 183.00 4555.20 4450.20 231500.02 2472147.36 -2081.55 182.60 1.02 2066.26 13 5204.00 27.75 184.00 4636.52 4531.52 231496.42 2472104.50 -2124.48 179.971 0.58 2109.27 14 5328.00 29.00 181.00, 4745.63 4640.63 231492.54 2472045.721 -2183.34 177.44 1.53 2168.17 1 • • Measured Angle Azimuth TVD -RKB TVD I X Y N / -S E / -W DLS Vert. Sec ----- - - - - -- ------- - - - - -- - - - - - -- - - - - - -- - -- -- -- - - - - -- SVY# Depth deg deg ft Subsea 1 ft ft ft ft deg /100 ft ft 15 5411.00 30.00 I 183.00 4817.87 ( 4712.87 231490.18 2472004.92 ] - 2224.18 176.00 1.69 2209.02 16 5605.00 ! 29.75 I 182.00 4986.09 4881.09 231483.76 2471908.51 32 20.72 ; 171.78 0.29 2305.64 17 5782.00 28.75 185.00 5140.53 5035.53 231476.56 2471822.35 - 2407.02 166.54 1.00 2392.10 18 5948.00 28.25 188.00 5286.42 5181.42 231465.82 2471743.90 - 2485.70 157.59 0.91 2471.18 19 6136.00 28.50 184.00 5451.85 5346.85 231454.48 2471655.32 - 2574.51 148.27 1.02 2560.40 20 6294.00 29.75 187.00 5589.87 5484.87 231445.34 2471578.99 - 2651.03 140.86 1.22 2637.23 21 6340.00 29.75 188.00 5629.81 5524.81 231441.84 2471556.43 - 2673.66 137.88 1.08 2660.00 22 6511.00 30.00 192.00 5778.10 5673.10 231425.1_5 2471472.96 - 2757.50 123.09 1.17 2744.59 23 6634.00 30.00 191.00 5884.62 5779.62 231411.52 2471412.99 - 2817.76 110.83 0.41 2805.50 24 6791.00 30.50 189.00 6020.25 5915.25 231396.03 2471335.44 - 2895.64 97.101 0.72 2884.08 25 6917.00 30.75 189.00 6128.68 6023.68 231384.55 2471272.29 - 2959.04 87.06 0.20 2947.98 26 7109.00 30.251 192.00 6294.12 6189.12 231364.64 2471176.93 -3054.83 69.33 0.83 3044.68 27 7204.00 30.75 196.00 6375.98 6270.98 231351.91 2471130.45 - 3101.59 57.66 2.20 3092.07 28 7265.00 30.00 189.00 6428.62 6323.62 231344.54 2471100.55 - 3131.65 50.971 5.93 3122.49 29 7296.00 30.75 187.00 6455.37 6350.37 231342.01 2471085.08 - 3147.17 48.79 4.06 3138.12 30 7424.00 30.50 184.00 6565.52 6460.52 231334.28, 2471020.35 - 3212.06 42.54 1.211 3203.27 31 7579.00 30.00 187.00 6699.42 6594.42 231325.05 2470942.84 - 3289.76 35.07 1.03 3281.28 32 1- 7763.00 31.00 187.00 6857.96 6752.96 231311.56i 2470850.44 - 3382.45 23.69 0.54 3374.50 33 7987.001 31.50 187.00 7049.46 6944.46 231294.78 2470735.45 - 3497.791 9.53 0.22 3490.50 34 8067.00 31.25 188.00 7117.76 7012.76 231288.41 2470694.29 - 3539.08 4.09 0.72 3532.05 35 8214.00 31.50 189.00 7243.27 7138.27 231275.38 2470618.88 - 3614.77 -7.22 0.39 3608.29 36 8268.00 32.25 189.00, 7289.13 7184.13 231270.28 2470590.83 - 3642.94 -11.68 1.39 3636.68 37 8393.00 32.25 189.00 7394.84' 7289.84 231258.35 2470525.20 - 3708.82 -22.12 0.00 3703.08 38 8649.00 31.50 191.00 7612.24 7507.24 231231.88 2470392.65 - 3841.94 -45.56 0.51 3837.39 39 8880.00 30.75 191.00 7809.99 7704.99 231206.43.2470275.99 - 3959.15 -68.35 0.32 3955.79 40 9033.00 30.25 194.00 7941.82 7836.82 231187.93 2470200.60 - 4034.94 -85.13 1.05 4032.48 41 9202.00 30.75 195.00 8087.44 7982.44 231164.56 2470118.08 - 4117.98 - 106.61 0.42 4116.68 42 9324.00 30.50 191.00 8192.43 , 8087.43 231149.21 2470057.89 -4178.50, - 120.60 1.68 4177.96 43 9438.00! 29.75- 195.00 8291.05 8186.05 231135.10 2470002.47 - 4234.23' -133.44 1.88 4234.37 44 9609.00 28.501 197.00 8440.43 8335.43 231110.38 2469923.01 - 4314.23 - 156.35 0.93 4315.64 45 9731.00 28.00 200.00 8547.90 8442.90 231090.83 2469868.70 - 4368.98 - 174.65 1.23 4371.41 46 9769.00! 26.75 195.00 8581.65 8476.65 231085.19 2469852.17 - 4385.62 - 179.92 6.88 4388.35 47 9830.00 26.25; 192.00 8636.24 8531.24 231078.23 2469825.87 - 4412.08 - 186.28 2.34 4415.15 48 1 10024.00 28.25 188.001 8808.72 8703.72 231060.94 2469738.80 ] - 4499.53 - 201.59 1.40 4503.38 49 j 10094.00 29.00 187.00 8870.16 8765.16 231055.81 2469705.66 -4532.77 - 205.96 1.27 4536.83 50 10244.00 28.00 187.00 9001.98 8896.98 231045.47 2469634.84 - 4603.81 - 214.69 0.67 4608.27 51 10372.00 27.25 187.00 9115.39 ' 9010.39 231036.90 2469576.11 - 4662.72 - 221.92 0.59 4667.52 52 10516.00 26.00 190.00 9244.12 9139.12 231025.95 2469512.53 I -4726.531 - 231.42 1.27 4731.79 53 10647.00 27.75 190.00 9360.97 9255.97 231014.35 2469454.47 - 4784.85 - 241.70 1.34 4790.63 54 10769.00 ! 28.25 ! 192.00 9468.69 9363.69 231002.13 2469398.52 - 4841.06 - 252.64 0.87 4847.42 55 10926.00 31.75' 190.00 9604.64' 9499.64 230985.48 2469321.83 ! - 4918.11 - 267.54 2.32 4925.24 56 11015.00 33.00 194.00 9679.81 9574.81 230974.50 2469275.48 - 4964.70 - 277.47 2.79 4972.35 57 11173.00 29.75 197.00 9814.70 9709.70 230950.82 2469196.74 - 5043.96 - 299.35 2.28 5052.82 58 j 11282.00 ; 29.25 199.00 9909.57 , 9804.571230933.09 2469146.09 - 5095.00 - 315.92 ! 1.01 5104.79 2 • 1 H fto GY XTO ENERGY INC. MGS C34 -26 COOK INLET, ALASKA — EAST FLANK Return Well to Production Procedure WELL DATA: SURFACE CASING: 10- 40.5# J55 BTC. Set @ 1732'. Cmt w/ 1550 sk. LONGSTRING CASING: 7 " 23, 26 & 29# N80. Set @ 11,259'. Cmt w/ 1200 sk. TOC @ 7900' Surface — 4711': 23# 4711 — 8646': 26# 8646 — 11,259': 29# TUBING: 3 - /2" 9.3# N80 8rd EUE @ 10,683'. PACKERS: 4 ea 7" Guiberson Uni- Packer VII @ 9880', 10,331', 10,481' & 10,662'. Pkrs set in 1973. PERFORATIONS: GR -GS: 9919 — 26' & 9932 - 57' HC -HD: 10,247 — 56' & 10,284 — 305' HD -HE: 10,355 — 65' HE -HF: 10,397 — 453' HI -HK: 10,526 — 40' HK -HN: 10,547 — 644' & 10,690 — 752' HN -HR: 10,786 — 11,000' FISH: 2' 3 -1/2" tbg w/ Q Nipple @ 11,024' PBTD: 11,024' BHST: 170 Deg F BHP: *4500 psi (SI WHP = 500 psi) SMALLEST ID: 2.813" ID X Nipple @ 10,673' PRESENT STATUS: SI w/ 500 psi WHP & 350 psi Csg Press. OBJECTIVE: Replace 3 -1/2" GL string w/ 2 -3/8 ". • AFE # 1200385 • Prior to Workover, Slickline will run gauge ring to determine the condition of the tbg ID for WL jet cut. If tbg is scaled up, Coil tbg will be used to clean -out the tbg ID. • The entire D Compact Wellhead will be replaced which will require cutting & replacing the top 150' of 7" casing. • Need 11" x 13 -5/8" clamp adapter for BOP. 8 -14 -12 Y: \PLF\alaska \Procedures \C34 -26 \C34 -26 RWTP Procedure 8- 14- 12.doc • 0 2 Equipment: • RHCP Plug (Pollard) Installed in 2 -3/8" XN. • 4' drop bar w/ ball (Pollard) Materials Rqd: • 5 gal WC1447WR Corrosion Inhibitor (Nalco) • 5 gal EC6112A Biocide (Nalco) • 100 bbl Gel Pill (2 #/bbl FloZan + 3 gal Greencide) (Provided by MI) • 67,000 lbs CaC1 (112 lbs/bbl FIW to build 10.3 ppg) Maintain MW from last well. 8 -14 -12 Y: \PLF\alaska \Procedures \C34- 26\C34 -26 RWTP Procedure 8- 14- 12.doc • • 3 PROCEDURE: 1. Bleed -off well to header. 2. RU Slickline & lubricator. RIH w/ 2.70" gauge ring to X nipple @ 10,673'. Reduce gauge OD if the 2.70" will not get DH. RIH w/ pulling tool to GLM #8 @ 9835'. Latch & POOH the dummy valve. RD lubricator. 3. MIRU Derrick. Mix up 400 bbl 10.3 ppg CaC12 mud (use from last WO). Circ to kill well through ✓ GLM #8 @ 9835'. Take wellbore fluids to disposal well and recover /maintain the 10.3 ppg Salt mud. 4. SD & monitor well for 60 minutes to make sure well is dead. 5. Notify the AOGCC 48 hrs prior to BOP test. Set BPV. ND WH. Set 11" 5K x 13 -5/8" clamp adapter. NU riser & BOP's. Pull BPV's & set 2 -way check valve. Press test BOP's to 250 psi & 5000 psi. Send D Compact WH to OS for scrap. 6. MI 11,400' 3 -1/2" 15.5# S135 drill pipe & 6 ea 4 -3/4" DC's. 7. MIRU Pollard WL. RIH w/ Radial Torch cutter & CCL. Cut the tbg ±5' below the SS a 941': POOH. Observe the quality of the cut tbg as per Step #21 if stub will require a dressing. Leave WL on board for Step #17. 8. RU slips & tongs for 3 -1/2" tbg. POOH & LD 3 -1/2" tbg w/ 8 GLM's while checking for NORM. Send tbg & GLM's to onshore to be sold for scrap. Casing Cut for Csg Spool Removal: 9. MI 4 jts 7" 29# L80 BTC. 10. RIH w/ HOWCO 7" 23# RBP & set (ai 500,. Close pipe rams & press test to 1000 psi. POOH. Drop 500 lbs (20') of sand on top of RBP. 11. MU 7" casing cutter on DP. RIH & cut the 7" csg ±20' below the WH assembly. Circ out any gas. POOH & LD cutter. 12. ND BOP's. 13. Remove the bottom clamp from bottom of D Compact WH. LD WH w/ casing hanger & the 20' 7" casing stub. 14. NU new Cameron clamp x flange casing head. 15. NU BOP. 16. Press test the new clamp against the RBP to 3000 psi for 30 min. 8 -14 -12 Y:\ PLF\ alaska\Procedures \C34- 26\C34 -26 RWTP Procedure 8- 14- 12.doc 4 17. RIH w/ 5 -3/4" ITCO Spear w/ 2.0" ID and engage the top of 7" & PU 5000# over string wt. RU Pollard WL. RIH w/ string shot & CCL. Apply recommended torque to 7 ". Fire string shot in collar between 100 -150'. Backoff casing at collar. POOH & LD ±3 jts csg. 18. RU Casing Crew. MU Triple Connector screw -in sub to 7" Csg. RIH w/ new 7" Csg & screw into collar. Screw on 7" swage w/ 1502 2" connection. RU mud pump and press test the 7" connection against the RBP to 2000 psi for 30 min. Bleed -off press. RD BOP's. Hang off 7" on slips in WH, make cut and install new Cameron Tubing Spool. 19. Notify the AOGCC 48 hrs prior to BOP test. NU BOP's. Set WH test plug in tbg spo ol. Press test BOP's to 250 psi & 5000 psi. 20. RIH and wash off sand & retrieve the 7" RBP @ 500'. 21. Based upon results from Step #7 - RIH w/ dress -off mill to dress off top of the 3-1/2" tbg stub @ ±9846'. BHA to consist of mill, casing scraper for 29# & MAGTRAP. LIGHTLY tag up on tbg stub @ 9846'. Dress -off tbg stub as per instructed. Reverse circ 20 bbl gel sweep. Make a casing scraper run as minimum if tbg stub dress -off is not necessary. P g rY . 22. RIH w/ Howco 7" RTTS packer to 9735'. CCL has collars @ 9719' & 9763'. Est circ w/ FIW. Set pkr. Perform MIT on 7" x DP annulus to 2000 psi. Monitor press for 30 min. POOH & LD DP. 23. MI 10,200' 2 -3/8" 4.7# L80 8rd EUE tbg (incl 3% excess). 24. RIH w/ TIW 7" HM -1 Retrievable Packer on 2 -3/8" 4.7# L80 8rd EUE tbg and land as follows: Item Length, ft Top Bottom 2 -3/8" 4.7# L80 8rd EUE 300 0 300 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 300 304 2 -3/8" Baker TE5 SSSV 1 304 305 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 305 309 2 -3/8" 4.7# L80 8rd EUE 9,386 309 9,695 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 9,695 9,699 2 -3/8" X Nipple (1.875" ID) 9 Cr 1 9,699 9,700 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 9,700 9,704 1 jt 2 -3/8" 4.7# L80 8rd EUE 31 9,704 9,735 7" TIW HM -1 Retrievable Packer L80 4 9,735 9,739 3 Jt 2 -3/8" 4.7# L80 8rd EUE 93 9,739 9,832 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 4 9,832 9,836 2 -3/8" XN Nipple (1.791" ID) 9 Cr 1 9,836 9,837 4' Pup Jt, 2 -3/8" 4.7# 8rd EUE 3 9,837 9,840 3 -1/2" x 2 -3/8" TIW SBR Stabbed on @ 9846' 6 9,840 9,846 8 -14 -12 Y: \PLF\alaska \Procedures \C34- 26\C34 -26 RWTP Procedure 8- 14- 12.doc 5 Gas Lift Design GLM MD TVD PORT PSC PSO #1 2198 2050 12 942 1000 #2 3786 3400 12 923 963 #3 4822 4300 12 903 934 #4 5621 5000 12 885 908 #5 6192 5500 12 863 886 #6 6768 6000 12 842 864 #7 7348 6500 14 815 845 #8 7930 7000 14 793 822 #9 8517 7500 14 770 799 #10 9101 8000 14 747 775 #11 9677 8500 14 Orifice Each GLM to have a 4' Pup Jt on top & 6' Pup Jt on bottom. 25. PU landing jt & stab 3 -1/2" SBR onto 3 -1/2" tbg stub at 9846'. 26. Pull SBR off seat. Mix up 20 bbl biocide /pkr fluid pill to contain 5 gal Nalco WC1447WR + 5 gal EC6112A in 20 bbl FIW. Circ pill down tbg w/ FIW. Under - displace pill by 10 bbl inside the tbg. Set down SBR. 27. Space out & make up and land new Tbg Hanger. Run in lock screws to energize hanger seal. 28. RU Slick line & press test lubricator to 4000 psi. RIH w/ 1.5" tool to 8200' to verify the SBR is stabbed onto 3 -1/2" tbg sub @ 9846'. 29. RIH w/ PXN plug & set in XN nipple @ 9836'. Press test tbg to 1,000 psi for 15 min. Monitor falloff. Cont to press up to ±3,500 psi to set pkr. Hold 4,000 psi on the tbg for 15 min. POOH w/ SL. 30. Set BPV. ND BOP's. NU WH w/ new tbg head adapter. Pull BPV. Set 2 -way check. Test WH to 5,000 psi. Pull 2 -way check. 31. RU SL. RIH & pull the PXN plug. RD SL. PWO gas lift. Paul Figel Engineering Manager 8 -14 -12 Y: \PLF\alaska \Procedures \C34 -26 \C34 -26 RWTP Procedure 8- 14- 12.doc • • f ro WELL SI 1988 PLF 3 -31 -12 ENERGY Present Completion MGS C34 -26 KB: 35' Cook Inlet, Alaska Water Depth: 73' MSL Leg 1, Conductor 3 / % API No.: 50- 733 - 2003 -00 OvAl Spud: 1968 r P.A'''' Tbg: 3 -1/2 ", 9.3 #, N80, EUE 8rd @ 10,683' Set 4 -15 -73 Surf Csg: 10 3/4 ", 40.5 Ib, J55. Otis Ball Valve 290' Set @ 1732'. Cmt'd w/ 1500 sx. GLM #1 2140' ALL GLM's GLM #2 4121' ARE DUMMY GLM #3 5650' GAS LIFT GLM #4 6912' VALVES GLM #5 7955' GLM #6 8756' GLM #7 9401' GLM #8 9835' Otis "X" Nipple 10673' Longstring 7 ", N80 BTC. Set @ 11,259'. EOT 10683' Cmt w/ 1200 sx. TOC @7900' 23# : Surface to 4711'. 26# : 4711 - 8646'. 29# : 8646 — 11,259'. OA iir V "XO" Sliding Sleeve 9841' � ��� Gv°1 tvb +r) / . J11 Uni- Packer VII 9880 ®�'7 - -- GR -GS: 9919-26' & 9932 -57 ' v HC-HD: 10,247 -256' & 10,284 -305' GLM #9 Dummy 10278' e "XO" Sliding Sleeve 10314' 1011 111 Uni- Packer VII ' 10331' ?/ HD-HE: 10,355 -65' SS @ 10,463' is Upside Down illl HE -HF: 10,397 -453' GLM #10 Dummy 10428' Otis "XO" Sliding Sleeve 10463' ,� �� Uni- Packer VII 10481' VI ' HI -HK: 10,526 -540' r,1 4 , , •••• HK-HN(u): 10,547-644' GLM #11 Dummy 10610' 1 r, Otis "XO" Sliding Sleeve 10644' �� j Uni- Packer VII 10662' 3.5" X Nipple (2.813" ID) 10673' =-------- HK- HN(I): 10,690- 10752' EOT @ 10,683' HN -HR: 10,786- 11000' 6.1110 , 4 FISH: 2' 3 -W Tbg w/ "Q" Nipple @ 11,024' (12 -4 -76) PBTD: 11024' �� TD: 11282' yy��' ; 0r�, . , . . • • ( To PLF 8 -14 -12 PROPOSED Completion MGS C34 -26 ` I KB: 35' Cook Inlet, Alaska Water Depth: 73' MSL Leg 1, Conductor 3 Tbg: 2 -3/8" 4.7# L80 8rd EUE. Set: API No.: 50- 733 - 2003 -00 Spud: 1968 4 ' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 300' 2 -3/8" Baker TE5 SSSV © 304' 4' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 305' ±303 Jts 2 -3/8" 4.7# L80 8rd EUE Surf Csg: 10 3/4 ", 40.5 Ib, J55. 4' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 9695' Set @ 1732'. Cmt'd w/ 1500 sx. 2 -3/8" X Nipple (1.875" ID) 9 Cr @ 9699' 4' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 9695' 1 Jt 2 -3/8" 4.7# L80 8rd EUE @ 9704' 7" TIW HM -1 L80 Retrievable Pkr @ 9735' 3 Jt 2 -3/8" 4.7# L80 8rd EUE @ 9739' 4' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 9832' 2 -3/8" XN Nipple (1.791" ID) 9 Cr @ 9699' 4' Pup Jt, 2 -3/8" 4.7# L80 8rd EUE @ 9832' Longstring 7 ", N80 BTC. Set @ 11,259'. 3-W x 2 -3/8" TIW SBR Stabbed on @ 9846' Cmt w/ 1200 sx. TOC @7900' i 2 GLM MD TVD PORT PSC PSO 3# :Surface to 4711'. #1 2198 2050 12 942 1000 26# : 4711 - 8646'. #2 3786 3400 12 923 963 29# : 8646 — 11,259'. #3 4822 4300 12 903 934 #4 5621 5000 12 885 908 #5 6192 5500 12 863 886 r i.m - glrj #6 6768 6000 12 842 864 0 rei #7 7348 6500 14 815 845 #8 7930 7000 14 793 822 Tbg cut @ ±9846' 0 ril #9 8517 7500 14 770 799 #10 9101 8000 14 747 775 Uni- Packer VII @ 9880' 1111.-224 #11 9677 8500 14 Orifice GR -GS: 9919 -26' & 9932 -57' (SQZ'd) lie# rop 1 90 d GLM #9 Dummy @ 10278' HC -HD: 10,247 -256' & 10,284 -305' XO Sliding Sleeve @ 10314' (Shut) g o a Uni- Packer VII @ 10331' 01.-m• rfarr O il .-_- _--- HD -HE: 10,355 -65' GLM #10 Dummy @ 10428' 2 I . • 1 pf XO Sliding Sleeve @ 10463' (Shut) HE -HF: 10,397 -453' (SQZ'd) SS is Upside Down (1973) Uni- Packer VII @ 10,481' HI-HK: 10,526-540' GLM #11 Dummy @ 10610' HK- HN(u): 10,547 -644' XO Sliding Sleeve @ 10644' (Shut) Uni - Packer VII @ 10662' ce0M ►� 3 -' /2" X Nipple (2.813" ID) @ 10673' leo HK- HN(I): 10,690- 10752' HN -HR: 10,786- 11000' 1, 4C:24 FISH: 2' 3 - %" Tbg w/ "Q" Nipple @ 11,024' (12 -4 -76) PBTD: 11024' 74 TD: 11282' . J ,. • • CAMERON XTO PLATFORM C Well 34 -26 Equipment CURRENT WH 8 -14 -12 war H., =i.i ' - © Block Tree - with Integral and additional SSV Wing OrAO 3 -1/8 API 5K Run with 2 -1/16 API 5K Wing O O 0 Valves on wing use R -24 Ring Gaskets D C , Tubing Hanger has 3 "Type H BPV Profile O O O a O O P is 1.O SSV i l ill O 0 40 0 w / 0 0: Lowermost Casing Head Type D Compact 11" 3K ( #9 Clamp) Hub x 11 API 5K ( #10 Clamp) Hub Top 1 _ j ; .4 1 t R -53 MODIFIED Ring Gasket Bottom !_r ,,, - 0 8' R -53 Ring Gasket Top Annulus Outlets are 2 -1/16 API 5K f R -24 Ring Gasket _ i 0, 9 ■ kg ° 1 1 ,,� i l� � � I' b , - 5' 11" _ 01 �•„ i 2 -1/16 API 5K .L� fill R -24 Ring Gasket 4 5 ..II,1 � ° � ''II III° �� • l of 1 i'1 , 3' 2 " 1= o i -e � ,� 2 ' 2 „ ra 2 -1/16 API 5K W R -24 Ring Gask =t • • CAMERON XTO PLATFORM C Well 34 -26 PRODUCER REPLACEMENT EQUIPMENT 2012 Well currently has a Cameron Type D Compact Wellhead Existing 7" Casing will be cut to allow removal of the D Compact Housing. A new Casing Housing will be installed, the 7" tied back and a new Tubing Spool installed. We will also replace the Tubing Hanger, Adapter and Tree *Equipment to be configured as shown *Equipment to be configured as shown ,, 2 -1/16 5000 Wing HWO and Pneumatic Trees configured the same as existing Actuated Wing valve with H2 Choke to be equipment currently on Wells per Shipped separate from run of Tree photographs 00 e 0 O- J W Replacement _ 2 -9/16 5000 Tree o 3 _ 2 o With 2 -1/16 5K Wing ° cy c , o om( Replacement Tubing Head Adapter °n 7 -1/16 x 2 -9/16 Stainless Adapter T -, , Replacement Tubing Hanger PN UNKNOWN O ff- 7 x 2 -7/8 EUE 8rd Stainless O N, � ��_� PN UNKNOWN Replacement Tubing Spool - CAMERON N 11 "5K x 7 -1/16 5K Top u■ I I, •� With (2) 2 -1/16 5K Valves -- Leave one of the Annulus Valves PN Unknown =z- I�II��� �� a„ o open ended to allow Line to be rigged J II NX Bottom Prep , _- � _ s,�, �� o )o up 10 r" Replacement Secondary Seal PN UNKNOWN Z11110 Replacement Slips Replacement Casing Head tl mot PN UNKNOWN PN UNKNOWN �I II �II�� o / � i� l1 • • 5/23/2012 13.625 BOP Schematic.xls XTO - ENERGY KB Elevation Date: 5/23/2012 "Rig Floor' Flow E Flow line Nipple Hydril / 13 5/8" 5m 13 5/8" 5m Annular double ram ` / preventer I FE MI WTI - I I r- �, 1::=01 �� 13 5 /8" 5m Cameron d i t 1 _--....e Pipe rams • 4 I I 13 5/8" 5m Cameron I I i �� j Blind R�ms IP . : #.__... ._._ -1 ■ • J •• / n ni 11 11 111 U �� ��:, It ''' ' i IF 1I II' 2 1/16" Kill Line 3 1/8 "Choke Line 111 11 11 111 11 • 2 1/16" rc 1/8\ 3 1/8" 5>m 5m 5m Hydraulic Manual Manual Valve Valves \ valve 135/8 / riser 13 f/ 135/8 "5m I wil11WI111 it' Mud Cross with 3 1/8" outlets Page 1 AIF,A KA OIL AND GAS CONSERVATION CODMSSION December 16, 2009 Dale Pittman Alaska Production Manager ExxonMobil Production Company PO Box 196601 Anchorage, AK 99519 Re: Acquisition of XTO Energy, Inc. Dear Mr. Pittman: SMIJEU OCT 06 {014 Congratulations on your acquisition of XTO Energy, Inc. Attached please find information on three XTO-operated wells in Alaska. The Alaska Oil and Gas Conservation Commission requests that you confirm or update the wells' status and plans. Sincerely, p Cathy. . Foerster Commissioner (2) Enclosures SEAM PARNELL, GOVERNOR 333W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 f PHONE (907) 279-1433 FAX (907)276-7542 SMIJEU OCT 06 {014 Congratulations on your acquisition of XTO Energy, Inc. Attached please find information on three XTO-operated wells in Alaska. The Alaska Oil and Gas Conservation Commission requests that you confirm or update the wells' status and plans. Sincerely, p Cathy. . Foerster Commissioner (2) Enclosures ; N- ERGY July 27, 2009 Ms. Cathy P. Foerster, Commissioner State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 Re: Request for Information — Status of Oil and Gas Wells Dear Ms. Foerster: JUL u 1 2009 1hs'Ai ilii Cs t copis. [arniAssictrt XTO Energy Inc. (XTO) has received a request dated June 22, 2009, pursuant to 20 AAC 25.300, requesting information about the status of three wells located in the Middle Ground Shoal field of Cook Inlet, which is operated by XTO. Commission records indicating that these wells (A42-14, C24-26RD, C34-26) have been inactive for five years or longer are correct. The A42-14 (167-014) has been inactive since September 1998 when it produced 6 bopd & 294 bwpd. The well was shut-in in October 1998 because it was no longer economic to produce. Since that time it has remained shut-in with production tubing and packers installed in the well. XTO has plans to utilize this wellbore for an east flank sidetrack when economic and budget conditions are sufficient to justify re -activating the drilling rig on Platform A. The C24-26RD (179-062) has been inactive since May 1992 when it produced 24 bopd & 660 bwpd. The well had been active intermittently from 1988 until it was shut-in in May 1992 due to the high water cut. Since that time the well has remained shut-in with production tubing and packers installed in the well. XTO is evaluating this wellbore for its use in drilling a sidetrack well targeting additional reserves in the west flank. The timing of future work will be determined by economic and budget conditions. The C34-26 (168-019) has been inactive since November 1988 when it produced 10 bopd & 80 bwpd. The well was shut-in due to uneconomic production. The production tubing and packers remain installed in the well. XTO is currently evaluating the potential of returning this well to production in the current configuration. In the event that this attempt is not feasible or is uneconomic, the well will likely be suspended during a future drilling program when the rig is available. Should you have any further questions or need additional information you can contact me at 432-620- 6742 or jeff gasch@xtoenergy.com. Sincer J f asch Operations Engineer XTO Energy Inc. XTO Energy Inc. - 200 North Loraine, Suite 800 - Midland, Texas 79701 - (432) 682-8873 - Fax (432) 687-0862 i1LJ1� SARAH PALIN, GOVERNOR L ,.�v �-, •►7-Ea . M G AND � � 333 W. 7th AVENUE, SUITE 100 CO3Y9,13 rZAMMNT CGM31190EG,Y ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907)276-7542 June 22, 2009 Kyle Hammond Vice President XTO Energy Inc. 200 North Loraine, Suite 800 Midland, Texas 79701 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Hammond: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by XTO Energy Inc. have been inactive for five years or longer. If, for any listed well, XTO Energy Inc. believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, XTO Energy Inc. agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve XTO Energy Inc. of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubert��alaska.gov. Sincerely, 4hyyFoerster Commissioner Enclosure 03/01/2002 15:47 FAX 9077766635~ ( UNOCALe UNOCAL GRAYLING Monthly Injection Report i~] O02/O04 Page'~ of I WATERFLOOD INJECTOR MONTHLY REPORT GRAYLING PLATFORM . G- 16GH. 507332016200501 Hrs Volume Tbg 7 Csg 9.625 Csg Well Date On Injected Press Press Press G- ! 6GH 2/1/02 24 3757 2950 1800 280 G- 16GH 2/2/02 24 3607 3000 1800 275 G- 16GH 2/3/02 24 3465 2900 1800 275 G- 16014 2/4/02 24 3541 3000 1700 275 II II G- 16GH 2/5/02 24 3593 3000 1750 275 I Illl la 1 G- 16OH 2/6/02 ~4-- 3807 3050 --] 7-00 270 I Ill II II Illl G. 16GH 2/7/02 24 3827 3000 1700 280 O- 16GH 2/8/02 24 3799 3000 1800 275 , G. 16GH 2/9/02 24 3747 3050 1850 270 Illl I i~l lift O- I6OH 2/10/02 24 3775 3050 1850 280 i i iii i i ~ ..... ! i i G-16GH 2/11/02 24 3735 3050 1950 , G-16GH 2/12/02 24 3747 3100 1900 275 G- 16GH 2/13/02 24 3741 3100 1750 270 II Ill G-16GH 2/14/02 24 3674 3100 i 750 270 i ii i i i Illll i O- 16GH 2/15/02 24 3666 3050 1700 260 G- 16OH 2/16/02 9.5 2427 3050 1700 260 II iiii Ill II i i iq G- 16GH 2/17/02 14.5 2434 3000 1900 280 . J i II I II I G- 16GH 2/18/02 24 1201 3000 1900 280 G- 16GH 2/19/02 0 0 325 1700 300 I II II II ',G- 16GH 2/20/02 24 0 250 2000 300 G-16GH 2/21/02 24 0 275 1750 310 I I I I Il G- 16GH 2/22/02 0 0 250 1800 320 Illllll I Illllll G- 16GH 2/23/02 24 0 250 1850 3~0 .... I I I [ I G- 16GH 2/24/02 0 0 250 1850 320 G- 16GH 2/25/02 24 0 200 1950 320 III ill i i lB G- 16OH 2/26/02 24 0 200 1950 320 I I Ill Illl Illl G- 16GH 2/27/02 24 0 200 1950 320 I II I Illllll G- 16OH 2/28/02 24 0 200 I700 27~- .............. You ,am user number 236 on this webslte and this page has been hit 9 times since 10/27~2000 http :#kodiak.anchortown.unocal.com/Surveil lane~/Illjgctor_Variance Report. asp 3/1/02 02/01/2002 01:00 FAX 9077766635 UNOCAL GRAYLING UNOCALe Monthly Injection Report Ig-l~gH ~ panua, S ~ ~.~J OO2/0O4 yage I ol I WATERFLOOD INJECTOR MON'FHLY REPORT GRAYLING PLATF()RM. G-16GH 5073320t6_.tJ0." ';01 iii ii i Hrs ~ olume Tbg 7 Csg 0.625 Csg ~,'~ ell Date On Injected Press Press Press G- ! 6Gl 1 I 'l 02 24 3(,78 2o50 1850 285 G- 16(_,H 1 2, 02 24 358~1 205{} 190(I 285 G-16GH I '3/02 21 3874 3000 19110 2S5 G- ! h(, H 1,'4, 02 24 3660 3 0(I() 1900 285 Illl iii iii i i I i i i iii ii iiii ii iiiii G- 16(7,1..I I,,5/02 - 1208 280o 2000 kl- 16GH 1/6'02 ~4' _ 3791 . 2~)50 1850 285 i iiiiiiiii III II i i IIii i II I iiii G. ! 6L, H 1/7/02 24 3749 3000 1750 280 IIII I 1I t I IIIIIII I I I I I I I III I I G-16GH !,8,02 24 3784 2950 1800 290 G- 16G! t !/9/I)2 24 3704 2950 1780 290 'G'ibGll 1, 10, 02 24 3708 3{)5(! 1780 280 ......................................... G-16GH I '1 I 02 20 5 3385 3025 1781) 280 G-I 6GH I 12 02 24 .... 18'* ~9r)0, ! 850 _8 ~G-16OH !'13" 24 1.)_ 3647 2900 1850 28(I .i iv,y.[ .ti LL , - . i G-16(;H I,'14'()2 19 2887 2000 1875 _8. ....... G-16GH !/! 5,'02 24 3956 3050 1800 280 Ii Il I . iiiiiiiiiiiiiiiiiiiiii i ii iii G-16GIt 1:16;02 24 39¢4 3100 1850 285 iiiii ii ii ,, , ,, i ....... ii z ...... ,,~ ........ - G-16GII 1!!7/02 24 3808 ~ 100 1860 _85 .......................................... .... ±ill I1~ IJ JJl III G- 16OH ! :18/02 21 3739 3(}00 1850 285 .... '.G. 16GH I/10/02 24 3712 30~ ~0 1900 290 _ G- 16Gtl 1, 20;02 24 3794 3050 1850 285 .... .... .......................... 'G-I6GH 1,21,02 24 3829 3000 1825 28(~ [1 ii iiii 11,11 ,111 iii , ii i :G.16GH I 22 02 24 3799 3000 ..~ 1825 280 ii i i ii iii [ i ii ........... :G-16GH ! 23,02 24 3665 3000 1800 280 (;- ! 6OI-I 1/24/02 24 3860 31 t)O 1800 270 ........................................... (3.16GH 1/25,o2 24 4022 3050 1750 280 ................... G-16(JH !/26/02 10 5 1719 3050 175(I ' ?80 G- 16GH 1,27,'02 o ~ 1863 3 i 00 1950 28(I , iui , ii i ' q ~ ......... ~,! LL G-16~'l-I ..... !,28.,02 24 4576 3300 1750 280 (.T- 16GH 1 '29,02 24 4553 33('~o 1700 2 ? 5 O-16OH !.30/02 24 4522 33(')t~ 1750 2?5 (,. 16GH 1 '31 '02 24 4483 3350 180(I 28o http://kodiak.anchortown,unocal,com/Surveillance/In, jector_VananceReport asp 2/1/02 01/01/2002 01:28 FAX 9077766635 · UNOCAL GRAYLING [~ 004/0O4 Page l of 1 JO-16OH .:J iDecember ~ Nlonthly Injection Report WATERFLOOD INJECTOR ~IONTHLY REPORT G[L4¥L[NO PLATFO1LM. ~- 16GH ~07332016200501 Well Date Hfs Volume ]-fig 7 Csg 9.625 Csg On l.jected Press Press Press G-16GH 12/b01 12 5 3077 3050 18(10 290 O- 16GI-I '' 1'2/2,01 24 ' 3905 3000 180b .... 2~j0 1111 I II II , G-16GII 1213101 24 3875 3000 l~00 290 ~ll ~ ' I I I G-16GH 12/4/01 24 3933 3050 1700 2~0 G'I6GH ' 12/5/01 "~ ....... 3855 3000 "'1760" G-16GII 12,6/0I 24 3893 3o25 i~O6' 285 G- 16GH 12/7/01 24 3935 3(;00 1875 28'~' , - ~G-16GH 12/8/01 24 3981 3150 1850 285- :G-16GH 12/9/01 24 3857 3050 1800 285 G-16GH ' " 12/10/01 24 2764 3O50 1850 290 G-16GH 12/I 1/01 24 3964 3000 1850 280 ,,,,, , . , . ..... _ ...... G- 16GH 12/12/01 24 3946 3o00 1850 280 G-16GII " 12/13/01 24 4076 3 ~00 ~800 2~- ........... ~ .~.. G-16GH 12/14/01 14 ' 2025 2900 1850 285 , ~ G-16GH 12/15/01 0 0 2900 1850 285 G- 16GH 12/16/01 0 0 2900 1850 285 ....... G- 16GH 12/17/01 24 969 2250 1650 265 G-16GH 12/I 8/01 24 3843 3000 1750 290 ., G- 16GH 12/19/01 24 3836 3000 1700 280 G-16GIt 12/20/01 24 3718 3100 1600 ................... Ill I I III I i, u i G. 16GH .......... 12/2 l/01 24 3637 ~(' ~ 00 1700 280 G-16GH 12/22,01 24 3790 3000 1950 290 , . O' 16GH 12/23/01 24 392~ 3050 2000 29~ G- 16GH 12/24/01 24 3756 2950 1950 286 . . . G-16GH 12/25/01 24 3630 2950 1950 285 G- 16GII ! 2/26/01 24 3549 2000 1900 282 G-16GH 12/27/01 24 3507 3000 ~9~ 2~6 .... ........................... G216GH 12/28/01 11.5 2194 3000 1950 280 i i ............ ............. G-16GH 12/29/01 24 3862 3000 1950 2~ ....... ~: ....... ~....t....u ...... _ : ........................... G-16G}I 12/30/01 24 3699 3000 1900 280 G-16GH 12/31/01 24 3619 '_9.0q ! 825 285 ,, .. ,,,,..,,][. ,, ,1 .... ...,..,.~ http://kodiak.ancho~own.unocal.com/Surveillance/Injeetor_VarianceReport.asp l/1/02 12/03/2001 00:58 FAX 9077766635 UNOCAL GRAYLING ~ 002/004 ' ( ( Pagcl~'~ I l//-II~~_~~ Monthly Injection Report ~,o M~ Ia'im' ......... iN°v b*;'3 W~ tTERFLOOD INJECTOR MONTHLY REPORT O~ ~O P~O~ O-16OH: 5073320162~S01 We~ Date ~ V°l~ Tbg 7 C~ 9.05 Csg !G-lt GH 11/1/01 24 3772 3~ 18~ 310 i G- It OH 11/2/01 ~ 3798 3~ 18~ 310 G- 1~GH 11/3/01 ~ 3761 30~ 18~ 310 I I Ill l G-It OH 11/4/01 24 3780 30~ 1750 310 G-It GH 11/5/01 ~ 3934 3050 18~ 310 II II G-it GH 11/6/01 ~ ~06 31~ 1750 308 I II i G-It DH 11H/Ol 24 4030 31~ 1750 310 _ G-It GH 11~/01 ~ 3914 31~ 17~ 300 G-l( GH I I~/01 24 3714 3100 17~ 280- i n i i ~1 G- 1(GH 11/1010i 24 3642 2950 17~ 3~ G-It GH 11/1 I~I ~ 36~ 2950 17~ 300 G- 1( GH 1 I/1 ~01 ~ 3458 3000 17ffi 290 ,, G-I( DH 11/13/01 24 1115 3~) 17~ 290 ~G- 1~ GH 11/14/01 0 0 350 18~ 111 i G- 1~ GH 11/15/01 24 2225 2800 1~ 290 __ . G-I( GH 11/16/01 ~ 3928 3~ 1750 290 ,........ G-l( OH 11/17~1 23 5 3708 30~ 17~ .... ~j iiiiii ii i . i i i L G-It GH I 1/18/01 ~ 3715 3~ 17~ 290 O- I~OH 11/19/01 24 36~ 2900 1850 290 G-It GH 11/20/01 24 3630 29~ 1775 290 Ill I I Ill G-I~ GH 11/21/01 ~ 37~I 3~ 1775 290 I.L O-1t GH 11/22~1 ~ 3685 3~ 1750 290 ii i ............. ~ll II I I ~O-ll OH 11/23/01 24 3659 2950 1750 280 I I II G-l{ aH 1 ln4/O1 24 3682 29~ 1750 290 [G_~tOH "' 11/25ml 2~' 3781 ' 3~ 1750 ' 290 ......... G- 11 OH 11/26/01 ~ 3833 3050 1750 280 I I illll Illll G-l{ GH 11/27/01 ~ 3799 3000 18~ 290 ii i i _ G- 1( OH 11/28/01 24 3803 3~ 18~ 290 ,I G- 1~OH 11~9/01 24 3874 3050 1750 2~0 G- I(GH 11/30/01 ~ 3899 3050 18~ 290 Ill I You ~~ user nm~r 263 on ~l, w,~ ~d ~ page ~ ~,n hit 28 m~ sm~* 10127/2~, h~p]/&odi~.~chortown.unocal.co~S~mHance~jectoLVm~ceRepon, asp 12/3 1 15'05 FAX 9077766635 ( UNOCAL GRAYLING ~002/004 Page 1 of I Monthly Injection Report WATERFLOOD INJECTOR MONTIILY REPORT (IRAYI,LNG I'LATFOP. M O. 16(1tt $0733201620(1501 I i - llllllll' __ ! iii Well Date ~rs Volume Tbg 7 Cs~ 9,625 I ~ ~jc~d P~ss Press . Press ~-I6GH 10Il/0:"- U 0 ' - 0 1750 ' ..... ~:6Oll I0~'i ............ 24 31~ 2900 650 340 i O- l 6GH l 0/W01 i 24 4208 2950 1800 G- 16GH 101,I/01 24 4096 2950 1800 33 '~'~ ...... .,- ~, ,e.. " ~- 1OGH 10/5/01 24 J 126 2950 1900 320 ......... J, ................... ~ .... ~ .... t,., O-I oOH 10/6/01 2~ 4068 Io0o 1850 320 O-16OH I0~/0 i 24 4080 3000 1875 325 qS-16OlI 10t8/01 24 4018 3001)......... 1950 330 ...... G-16GI [ 10/9/01 24 396~ 295([ ~ 1700 320 im ~ ~' G-1 oGI I 1 O/lU/O 1 24 3u65 2 990 I 8oo 320 G- 1 bGI I 10/11 I01 24 4V35 ~050 1825 340 ,,, .... ' .... :--; '2 ~...2.~,2 q:l~OI I 10112101 2 I' 4039 3000 1825 320 . , G-16GH 10/13/01 24 4U84 3050 1825 320 ...... --, m ......... ~-16Olt 10/14/01 24 4~g5 3025 ] 900 , 33U G-16GI I 10/1510 t 24 3982 3000 1800 330 ... ~ 16OH 10/16101 2,1 3997 3000 I gOO 320 --~ G-16GH 10/17101 24 3958 3000 1750 320 ii G. 16GH 10/I 9/01 24 3995 3000 17tX) 320 :G-16OIt 10/20/01 24 3995 3050 18~0 33 - -- z ...... -"~'?.~ ..... ' ....... .,..- .--r,. G- 16GH 10/21t01 24 3870 3050 1800 320 ................. ~. , , ,.,, .,.~,~ .... G-16GII 10/2Z/01 24 3923 3050 1750 325 :7.~ IS ~ .... L:- . :' J .............. -. . (N16GIt 10/23/01 24 3894 3050 1750 310 .......... ~.m ~ r:::::: ...... . .. G_ - 16Gt 1 10/24/01 24 3898 3050 1700 32 t'u" " ......... ~16GH 10/25101 24 3 ~ l 0 3050 1700 .20 ............ ~., .~ .... ... G-I 6Gl I 10/2~/01 24 3832 3000 1600 300 ...... . .__ · %~:::-.:,:.:t,.~_._,~ G-16Gl I 10~7/01 24 3815 3000 1650 310 G-16GII 10/28/01 24 4001 3050 1050 310 ........ . ~ Il' ..... c~:'J'6~i~ 10/29/01 24 ~ g~7 3000 ] 580 315 O-I 6~1,t 10/30/01 24 3878 ~ 1 oo 18~0 315 ii G-16GII 10/31/0i 24 [ ......... 3840 3100 1850 315 I 1/1/01 10/01/2001 01-57 FAX 9077766635 UNOCAL GRAYLING 0002/004 Page 1 o£ 1 UNOCAL Monthly Injection Report ... __ WATERFLOOD INJECTOR MONTHLY REPORT GRAYLING PLATFORM- G-16GH 507332016200S01 Well Date Hfs Volume Tbg 7~sg 9.625 Csg .......... ~n ........ Injected Pres*, Press ......... Press 'G - 16GI l 9/1/01 2.1 4106 3000 185 (') 325 ~16GI I 9/2/0 ! 24 4105 3050 1850 330 G-16GI.I 9~/01 24 4113 3100 1800 330 ............... ii~ G-16GH 9/4/01 24 4103 3100 1850 .................. 330 G- 16GH 9/5/01 24 4112 3100 1850 330 ............... G-16GI l 9/6R) I 24 ~ I48 2'950 1850 330 " ......... ~,.. ': ........... t.__s~ G- 16Gl [ 9~/01 24 4 l 41 2900 1850 ~0 G-16GtI --~- ......... -::-~-_: ~ ~ ....... 9~/0 ! 2 ~ 4155 3050 1850 ~ 30 G-I 6GH 9/9/0 i 24 4089 3050 1800 330 ....... G-16GH 9/10~I 24 4086 3050 I ~00 320 ......... }G-IOGH 9/1 l/0l 24 4053 30()0 l g00 325 (}-16~}H 9/12/01 24 4064 3 ] 00 ] 700 335 G- 16OH 9/I3~ I ~ 6 2735 2650 210(l 340 G-16GH 9/14R) I 10 1726 2650 2 ] 00 340 ...................... G-16GII 9/15/01 0 2021 1000 2250 330 ..... . ~-'"'"~ ':": ...... :--"-:---7--: .... . -':~':-:'-'":"-:':~::" ,",'~'n:--'.~::-'.-.~:7:.,:.:..: ...... ~ ....... - G-16Gt[ 9/I6/01 0 760 ~0 1750 1750 G- 16Gl [ 9/17101 0 0 0 0 0 (}- l 0OH 9/18/01 0 o 0 o o G-16GI I 9/19/0 ! 0 0 0 0 0 G-I 6Gl { qf20/01 (1 0 0 0 0 ...... G-I 6Gl i 9/21/01 0 0 0 0 0 O-16OH 9~2/0l 0 .I ............... ~ ............. 0 0 0 O- 10OH 9/23~ 1 0 0 700 2000 350 ..................................... ::::::::::::::::::::::::::::::::::::: ~ .~:-~ (I-I 6(}H 9124101 0 0 700 1700 (1-16(~H 9t25/01 U 0 700 1750 370 O- l 6OH 9/26/01 0 0 700 1750 3 (}-16(;H 0127101 0 0 650 1750 370 O-! 6OH 9[28/01 0 0 650 1750 360 G-I 0Oil 9~ g/01 0 [) 6q0 1750 .......................... ,.u..,,m,,.., ( }-16( }}l gl30/01 ¢) (') 0 1750 aT0 Yon an.. u,~e.'~ number 100 on tlm wcb~ilc and thi~ p~..'/e has be. ca lut 17 hra~. strtc~ 10'27 http://kodiak, anchortown.unocal com/Surveillance/lnjector_VarianceReport asp 10/1/01 09/01/2001 03' 41 FAX. 9077766635 I~0CAL GRAYLING 1~002/004 Page 1 of' 1 Monthly Injection Report WATERFLOOD INJECTOR MONTHLY REPORT GRAYI.INO PLA'ITORM t~16GH 507332016200501 Well Date ] I-l,m Volume Tbg 7 Csg I 9.625 i On Injected ..... Press Press Press (T-16(}H $/I/01 [ 24 4449 0 850 290 G-I 6(}H 8f2101 24 4452 3300 } :;50 1350 ! i i iii G- 16OII S/3m I 24 4707 3300 1800 305 ._u, 1,, _ · G- 16GH 8/4/01 24 4597 3300 1900 320 ............... . .... G- l'6~'fi = 8/5101 24 4763 3 ~o0 ! 800 305 ........... i , G-16GH 816/01 _~4 1751 ~ 300 1800 305 ........ . , , :G- 16GH 8/7101 24 4702 ~ ~0(} 1800 305 ..... . .......... . .... - G-16GIt $/~101 24 4693 3300 1800 305 ............. - . (.~-16GH 8/9/01 24 ,1667 :1:!0(I 1800 305 .......... ........ G-16OH 8/10/01 24 4652 3.300 1900 325 .... ~--i~iGt I 8/11/01 24 4637 3300 1900 330 ~. i ..J...._l,J*_~::_-_-; ~ ~ ' .... : G- 16OI-t 8/12101 2,$ 4(~59 3300 1950 330 G'166H 8/13ml ...... ~'~'~ ~, 4700 3300 2000 ~25 G-16OH 8/14101 24 [ 4665 3300 2000 341) i ...... G-I~GH I '8/15/01 24 47i0 3300 1950 330 .......... : ............. {J-I 6OH 8/I 6/01 24 4706 3300 1950 330 O-16GH 8/I?/01 12 2578 1:20 2250 325 G-IOOH 8/18/01 24 4251 3050 1950 330 iiii Jill il I Illl O-16(}}t 8/1 ~)/(,) 1 24 4195 3050 1950 '~3o ............ .................. .... ;G- ! 6( ;11 ~/2o/(l t 24 416,1 24 a I 0o '~'4 0 .............. ~.. iii ......... ~_ i,._.1 iiiii ....... ~ .......... . . O-16GI I 8/21/01 24 4138 t 100 1950 330 · - :t,:.;::;;~--' _ . ' "' nil cl-I 6GH 8/22101 24 ,I 129 :3100 1950 '~o O-I 6(i1-1 8/23/01 I 24 4059 3000 ..... 1950 325 ,,._._...: ___ .,. · z_::~z.. O-16GH 8/24/(l l 24 408§ 3025 1900 (:}-16(H-I 8125t0 l 2,:[ 4043 3050 1950 330 O-16OH 8/26/0 ! 24 4053 3O00 1900 325 G- 16Gt I 8/27/01 24 :~066 3000 1950 32 5 ,I Ill I _. 27 , G- 16Gl I 8/28/01 24 ,I 081 31)50 1875 330 _ __ ,_j ., ................. _. __ ~.~e '-' G-t6OlI $/29/0 i 24 4(182 3[}50 1900 335 ......... :: G-16GH ..........8/30101 2.4_ 4089 _..~025 ........ 1850 [ 335 G. lOGit 8/3 l/t)l 24 ,~.085 3000 1850 325 ..z _ .:.: -..,,,. ,,,,,,, i i,: ..~__-- You am t~.~t nmnlw~:r 162 nn tl~l~ ~eb~tto ,.utd flu, ?~g~ haq bg~n l~it I )ttmea salve I0 27 2ilO0 http,//kodiak, anchortown,unocal com/Surveillance/Injector_VafianceReport asp 9/1/01 05/01/2001 oo 52 FAX 9077766635 I.~qOCAL GRAYLING ~]003/O04 WAT LOOD JE OR MOSTLY PORT [. G-I~H 1~ ~1~1 24 4332 31ffi 2050 ~-I~H [: ~01 24 5279 30~0 2~0 305 G-I~H [' 4B/01 15 24~ 2850 1~0 3~ G-i~H [ ~4/01 24 ~ 2800 1950 285 G.I~H l},, 4/5~1 24 ~83 2~ 1950 290 ~1 ~H ~ 4/6101 24 ~71 2900 2~0 290 I ~111111 II III ~[~H ~: 4~/01 24 ,~ .... ~55 28~0 2~ 290 ¢I~H ~: 4/WOI 24 4~7 2850 2~0 290 G-16GH I' 4/10/01 24 5439 31~ 2~0 295 G-1 ~H ~ 4/I1/01 24 ~15 3150 2~0 295 ~ ii iiii ~16OH ? 4/13/01 IS.~ 3701 2~ 2300 295 O-16GH [~ 4/14/0I 24 ' '5720 3150 2100 280 G-16GH .[~ 4115101 24 5810 3250 2100 195 ~I~H [.~ 4/16/01 24 ~6 32~ l~5 240 i , ,,,- ........... G-I~H , 4/1~01 24 5419 3300 1975 240 G-]6OH [,~ 4/19/0~ 24 5392 3~00 2~0 240 G-16~J~ 4/20/01 24 5376 33~ 2~0 240 ~-I6~H [.~ 4~I/01 ~ 5357 ~00 2~0 240 *16~H i~ n/~O1 24 5350 33~ ........ 20~ 265 ..... lam ~-I6GH I: 4~3/01 24 ~9 33~ 2~ 265 *~m~I 4~4/01 24 ' 3367 ~3'~ ..... 2~ 265 iii- i i ~I~OH,,, ~.. 4~5/01 24 5~9 3~00 2200 260 ,*I~H L. 4/2i~ l 24 5335 3300 2000 2~ O-16OH { ~27/01 24 5355 33~ 2000 260 ~-I~H ~ 4~g/01 24 5352 33~ 2000 260 :O-I~H [ 4~0/01 24 5~0 33~ 2000 2 ' 4B0~l 2a 5339 3250 1700 I http :#k.o j', .anchortown.unocal.com/SurveillancefInjector_VarianceReport.asp 5/1/2001 03/01/Z001 00' $$ PAX i ~ ?7766635 IYNOCAL GRAYLIN$ ~002/004 Page 1 o£1 Monthly Injection Report ............ _. WA! !ERFLOOD INJECIOR MONTItLY PORT PLATFORM. G-16GH 507232016200501 'F I --- - ......... mini ii _ II __ '~;Vell Date Hfs Volume Tbg 7 C~g 9.625 Csg On lnjectcd Press Pres s Press · G-160! ' /1/0! 24 5506 5200 1850 320 ~;-~6G~' '2/~m --' 24 " 54~ ]~00 .... zB~ -" ~2o '" ..... ~, G- 16GH, 2/3~ 1 24 5471 3100 1850 320 G. 16G~? 2/4/01 24 5559" 3 i'00 1850 320 M~ e I III I II ~ 16G}? 2/~/01 24 5532 310~ 1 gOO 3 ] 0 ~111 O-16GI ~ .... 2/6t01 24 5533 3100 I gOO 310 G-16C.}][ 2~/01 24 5516 3100 18(10 ....... 310 (}-I 6GH' 2/8/01 24 5540 3100 1 g00 3 i O' G-IOO}~' 2/9/01 24 5532 3100 1800 310'" G- 16GP,~> .,,. 2/I 0101 24 5438 3100 1800 310 ....... O-160~ 2/I 1/01 24 4612 3100 1800 310 ...... . II G.10OF:, ~12/01 24 4286 2750 2~0 250 "', m Ii i O- 1601"~ ,__ . 2/1. 3/0,. 1, 24 5017 3100 1450 290 (z-16(~}:, 2/14/01 24 5616 3100 14~'~ 290 ii m G-I 6GI~~ 2/15/01 2~ 5627 3100 1600 29~ , . G-16GH; 2/16/01 24 5523 3150 1500 295 m m .,.1~ m . m G.. t 60H~:,., ~17/01 24 5745 3150 1500 295 '- m mi H m m G- 16GH. ~18/01 24 5879 3150 1550 295 s; i . , .... .., G- 16GH 2/19/01 24 5903 3150 I700 300 G- 16OH, 2120/01 24 5942 3200 1700 300 G-IOGH, 2/21/01 24 4852 2900 2000 300 G- 16GH" 2~2/0 i 24 5050 ~ 100 2000 3000 ~' - .2, ~ .,, ~' ___ .__ , ,_ G- 160H,, ,,, 2/23/01 24 5133 3000 1950 700 ..... /mi i G- 16OH. .. 2/24~ l 24 ~013 ~000 2000 300 G-16GH 2/25/01 24 S~3 3100 20(;b 300 G-16GH~',,, 2/26/01 24 5183 3100 2000 300 ~-iOGIi,~,. 2/27/01 24 " 5969 3100 1900 300 " " " O-16GTI, ~R/01 24 6349 3150 1950 300 http://ko(:fiakdsurveillance/Injector_VarianeeReport.asp 3/I/01 02/01/2001 00:52 FAX 9077766635( Iml /UNOCALe - . You. http//ko~ {. UNOCAL GRAYLING Monthly Injection Report -. INJECTOR-MONTHLY REPORT O-16GH: 507332016200S01 D~te Volume Tbg 7 Csg Injected Press Press 1/1/01 0 250 1850 i/2/0I 0 250 1850 1/3/0I 0 250 1850 1/4f01 0 250 1850 I/5/01 0 100 1800 1/6/01 792 2500 1800 1/7/01 5267 3000 300 1/8/01 5616 3150 1850 1/9/01 5346 3100 1800 1/10/01 5741 3150 1750 1111/01 5654 3150 1750 1 / 12/01 5386 31 O0 1700 I/I 3/01 5444 3050 19850 1/14/01 5418 3050 19850 1/15/01 5420 3050 1900 1/16/01 5413 3050 1950 1/17/01 5384 3050 1900 1/18/01 5372 3050 1900 !/l 9/0l 4625 2850 1900 1/20/01 4633 2800 1900 1/21/O1 4615 2800 1850 !/22/01 4583 2800 1850 1/23/01 4578 2800 1750 l/24/01 4249 2800 1 go0 1/25/01 4446 2800 1900 1/26/0 ! 5108 3150 1950 1/27/0t 5274 3300 1950 1/28/01 5560 3200 2000 1/29/01 5574 3200 1850 1/30/01 5549 3200 1850 1/31/01 5516 3200 1850 numb,z. 177 on this w~l~ilm and h~im lmag~ ham b~a h,i 5 ~ ,into 10t27/2000 ,ak. anchortown.unocal.com/surveillance/Injector_VarianceReport.asp ~004/O04 Page 1 of ! ...... F c. _o_ .j_?4)O.{ 9.625 Press 345 345 3~ 345 355 300 315 315 310 310 310 310 310 310 310 320 310 310 310 310 210 310 310 32O 32O 320 320 320 320 2/1/01 01/01/2001 01:12 FAX 9077766635 UNOCAL GRAYLING ~003/004 Page i o£ i Monthly Injection Report - __ _ Return to Mare menu WATE FLOOD INJECTOR MONTHLY REPORT GRAYLING_z LATFORM G-I 6GH 507332016200S01 Well G-16GH G-16GH G-16GH G-16GH G- 16OH G- 16OH G-16OH G-! 6Gtt G-16GH O-16GH G-16GH G- 16OH G- 16GH G-16GIt G-t6GH G-16GH G-16GH {3-16GH G-16GH G-16GH G-16GH G-16GH G- 16GH G-16GH G-16GH G- 1 G-16GH G-16GH G-16GH G-16GH G- 16GH Date Hrs Volume Tbg 7 Csg 9.625 Csg On Injected Press Press Presn 12/1/00 24 4309 l 3000 1700 315 , 12/2/00 24 42 73 3000 ~ 1700 320 12/3/00 24 4443 3000 1700 320 12/4/00 24 4431 3000 1700 320 12/5/00 24 4420 3000 1700 315 12/6/00 24 4420 3000 1700 320 1217100 3 476 3000 i700 320 12/8100 12 2183 2800 1700 325 __ 12/9100 24 4485 2850 1400 320 12/I 0/00 24 4407 3000 1500 325 12/I 1100 24 4373 2950 1700 315 12/12/00 24 5015 3300 1900 315 .... 1 ....... 2/13/00 24 5656 3400 1950 315 .......... 12/14/00 24 5676 3400' -. 1950 315 -- 12/15/00 .......24 5675 3450 1950 315 12t16/00 24 5656 3400 1950 315 12/t 7/00 24 5633 3410 1950 310 .... 12[!.8/00 24 5624 3400 1950 310 12/19/00 24 5539 3350 1900 3'10 - 12/20/00 23 5 4355 3325 1900 310 ...12/21/00 24 5749 32{)t) 1o25 310 12/22/00 24 5697' 3200 1925 300 I, , ..... 12~23/00 24 .... 5695 3200 l 9'00 310 . 12/24/00 24 5766 3200 1850 310 __ 12/25/00 24 5722 3200 1850 310 .... ,,, ,, 12/26/00 22 5 5458 3200 1850 315 ___ 12/27/00 __ 16 5 3425 2900 I85'0 315 12/28/00. 24 3662 I 2200 - 1600 300 12/29/00 9 1175 2200 1600 300 -- ,, 12/30/00 ,0 i 0 250 2950 340 - 12/31/00 24t 0 I 250 185b 345 COMMENt C$1NG.3i50 BLED TO 1850 You are uaeI numa ,x 197 on flus webstte and tb~s page has been lut 2 times since 10,'27~2000 http'#kodiak., nchortown.unocal.com/Surveillance,qnjector VarianceReport asp 1/1/0 1 12/01/2000 02:11 FAX 9077766635 . UNOCAL GRAYLING ~ 004/004 Page 1 ofl Selected Rep¢,-~t Name Tbg String Injector Oata Chart G-lSGH - G-ISGH Selected Line X Axis Field Graph Style Date Created Time Period Size Last Month X Axis Field 3 Lines & Symbols 1211/00 Injector Data UNOCAL. Cook Inlet, Alaska 1211/00 440D z z ~ z ~ z~z ~ ~z ~ ~ ~zz zzz r¢' Ro*e p' Tbg Pressure rJ' csg Pressure F~' Outer C~g Pressure r~ Hfs on http'//kodiak.: nchortown, unocal eom/da/templates/graphic, asp 12/!/00 11/01/2000 02:42 FAX 907776663~ UNOCAL GRAYLING Page 1 of 1 004/0O4 WATERI LOOD INJECTOR MONTHLY REPORT GRAYLING PL,' TFORM G-16GH 507332016200S01 Dat~ Hrs Volume Tbg 7 Csg 9.625 C~g' On InJected Pres s Press Pres m i 011/00 22 4509 3250 1640 320 10/2/00 24 4938 3250 1700 315 1013/00 24 4914 3300 1700 315 ,, , 1o/~/oo 2,~ 4s29 3300 1680 315 to/5/oo ...... 24 4915 3350 1650 320 " t0/6/00 24 4905 3700 1650 330 10/7/00 23 4790 3300 1650 330 10/8/00 24 4685 3075 2000 325 I 0/9/00 24 47 l 1 3050 1950 325 I0/10/00 24 469i ' ' 3050 1950 325 10/1 l/D0 24 4693 3100 1900 325 , 10/12/00 24 ,1683 3050 1850 325' . ...... 10/13/00 24 4669 3100 1850 320 10lI4/00 24 4745 3100 1850 320 10/15/00 24 4500 3000 1800 320 10/16100 24 4501 3000 1700 320 ] 0/17/00 22 4023 ....... 3000 1800 320 10/18/00 24 4302 300~' 1825 '320 10/19/00 2,1 ~1227 3050 1800 320 10120/00 24 2296 ~0'00 1850 320 10121/00 24 4275 3000 1750 320 i0'~2.~/00 24 ...... 41~'7' 3000 1775 ' 320 , 10/23100 24 4510 3000 1800 320 10/24/00 23 5 4-¢25 3000 1750 320 10125100 24 ,I31~'" ' 3000 1750 320 10/26100 24 4353 3000 1800 320 ' 10/27100 24 ...... 4327' 3000 1800 " 325 10/28/00 24 4311 3000 1800 ~25 10i29/0~' 24 [ 4460 '~950" 1900 325 10/30/00 24 [ ....... 42'74 3000 1950 ....325 10/31100 24] 4414 3000 ....... 2000 325 .. Well G-16OH G-16OH G-16GH O-16OH G-16OH G-16GH G-16GH G- 16GH G-16OH G- 16OH G-16GH G~16GI-t O- 160I-I G-16GII G-16GH G-16OH G-16GH G-16OH G-16OH G-16GH G-16OH G-16GH G.16OFI G-16GH G-16GH G-16QH G-.16QH G-16GH G-16GH IG-16GH la-.leO}-: 5 ou ,~ro uam nutnbm /78 on fid, ~cbstt, ,md th. is page im~ been lgt 10 llm,~ m~cc It, 2~ 2o(10. http'//kodiak, a,':~chortown.unocal, com/Surveillanc e/Inj ector_VarianceRep ort.asp 11 / 1/00 09/01/2000 0~:13 FAX 90777666~,~5 UNOCAL GRAYLING [~]003/004 Page 1 of 1 lil -I. l Of. ALO Monthly Injection Report WA LOOD JECTOR MO HLY REPORT · ~UG-I~H 5073320162~S0l "t Well Date Hr~ Volume Tbg I 7 Csg 9.625 Csg -- ~..~ On Injected Press Pres.~ Press TBU G- [,~GH 8/1/00 24 4371 3000 2050 365 TBU ~" }!GH 8/2/00 24 4307 2950 1925 - 360 ~TBU O-I! IGH 8/3/00 24 4306 2975 1900 360 T--'~ ~' Ii (GH 8/4/00 24 4310 2975 1850 360 o- 3tt /5/00 24 4315 2975 1850 TBU O-l'~ OH 8/6/00 24 4313 2975 1925 360 'I'BU O- ii OH 8/7/00 24 4314 3000 1950 360 TBU ~a SH 8/8/00 24 4316 3000 1950 360 'TBU G-I~ ~H 8/9/00 2"'~'~ 4322 3000 1950 360 ~ ~BU G~3H 8/I0/00 24 4319 3000 1950 355 ~r'BU G-I'~ 3H 8/11/00 24 4329 3000 1950 360 TBLT G- 1~! ?I 8/12/00 24 4335 300 1950 360 TBU G-I~ 3H 8/I 3/00 24 4334 3000 1950 360 TBU G-I~ 3H 8/14/00 13' 2368 3000 1950 360 TBU O-l!~ 3H 8/15/00 24 4549 3000 2000 360 '~BU G-~ ~I'I 8/16/00 24 4488 3000 1950 360 'mu O-l~ m 8/17/00 24 4436 3000 I900 370 mU O-I ~'! 3H 8/18/00 24 ~~. 4409 2950 1850 370 TBU G-I~[! }~H 8/I 9/00 24 4404 2950 1850 370 ~3H 8/20/00 24 4405 2950 1870 370 TBU G~ 1 ~;," ;H 8/21/00 ~4 4410 2975 1850 370 ~3UG-I~ ~H 8/22/00 24 44t0 2975 1850 370 ~rBU G- 1 ,".~H 8/23/00 24 4431 3000 1850 370 YBU G- 1-~H 8/24/00 24 4431 3000 1850 330 'TBU O-l~ ~'l 8/25/00 24 4439 3000 1850' 280 ~TBU G- 16~ }H 8/26/00 24 ~Fi 4430 3000 1800 285 '~ O. 1 .. }H 8/27/00 24 4400 3000 1800 285 TBU G- ~H 8/28/00 24 4359 3000 1775 300 TBU O-i~ [}I 8/29/00 24 4365 2975 1800 305 TBU 0-I ~!fH 8/30/00 24 4322 3000 1800 310" .~i~H 8'31/00 24 4292 3000 1825 310 ,-i page ; tunes since 7/14/2000 8'23 AiM http/&odi~.anchonown unocal.co~Sumeillance/InjectocV~aneeRepoa, asp 911100 MAR. 1.2000 4:35AM UNOCAL OIL & GAS GRAYLING PLATFORM G-16 Injector Feb.2000 M0.095 P.2/4 2/24/00 2/',Z5/00, 2/26t00, 2/27/00, 2/28/OO 2/'29/00 1850 1800 1850 1850 1800 1800 1860 1850~ 1650 1850 1800 1826 1860 1800 1860 1860 1800 1800 18OO 1625 1825 1825 1800 1600 1800, 180( 35O 32O 32O 32O 320 3O5 305 306 310 310 310 31( 310 35O 305 31 3O6 300 3O5 310 31 305 3O5 310 31 300 300 4462 4735 48O6 4787 4652 ~irs # 5 ,s/f RECEIVED Shell Western E&P Inc. 601 West FIfth Avenue · Suite 800 ^nchorage, Alaska 99501 December 19, 1991 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Gentlemen: SUBJECT: SUBSEQUENT REPORT FOR MIDDLE GROUND SHOAL WELL C34-26; SUNDRY APPROVAL #91-257 Enclosed are duplicates of the Subsequent Report which cancels the proposed work to convert well C34-26 to injection. C34-26 is an offset producer location to C24-26. C24-26 is currently being evaluated for conversion to injection. If you need additional reports or information, please contact Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, /~ R. G. Blackburn Manager Alaska Operations Western Division RGB/SBBM/dlw Enclosures SBBM~121991.WP5 RECEIVED DEC ~ 0 1991 Alaska Oil & Gas Cons. Anchorage STATE OF ALASKA COMMiS~r ~ · ALA~ O,LANOGAS CONSERVATION 0 I~ I G IN A L REPORT OF SUNDRY WELL OPERATIONS 1 Operations pedormed: Operation shutdown __ Stimulate Pluggingm Perforate __ Pull tubing__ Alter casing m Repair well __ Other X 5. type o! Well: 6. Datum elevation (DF or KB) 2. Name of Operator Shell Western E&P Inc. Development X 116' KB feet 3 Address 601 W. 5th Avenue, Suite 810 Exploratory 7. Unit or Property name Anchorage, AK 99501 Stratigraphic Middle Ground Shoal Sewice 8. Well Number 4. Location of well at sudace Platform C, Leg 1, Conductor 3, 544.25'N and 1591.06'W of C34-26 SE Corner of Sec. 23, TSN, R13W, SM 9. Permit number/approval number At top of productive interval Platform C, Leg 1, Conductor 3, 3894'S and 1769'W of SE 68-0019/91-257 Corner of Sec. 23, TSN, R13W, SM 10. APl number At effectwe depth 50-733-20093.00 At total depth @ 4548'S and 1887'W of SE Corner of Sec. 23, TSN, R13W, 11. Field/Pool SM MGS/"E", "F", & "G" Pools 12. Present well condition summary Total depth: measured 11,282 feet Plugs (measured) true vertical 9908 feet Effective depth: measured 11,024 feet Junk (measured) true vertical 9692 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1732' 10-3/4", 40.5#, J-55 1500 sx 1732' 1642' Intermediate 11,259' 7", 23-29#, N-80 1200 sx 11,259' 9889' Production Liner Perforation depth: measured 9919'-11,000'(10 Intervals) true vertical 8720'-9672' Tubing (size, grade, and measured depth) 3-1/2", 9.3~, N-80 EUE 8rd @ 10,683' Packers and SSSV (type and measured depth) Guiberson Uni-VII @ 9880', 10,331', 10,481', 10,662'. Otis SSSV @ 290'. I V I- 1 ~. Stimulation or cement squeeze summary Intervals treated (measured) This procedure has been cancelled DEC 0 191tl Treatment description including volumes used and final pressure Alaska 0JJ & (~as Coils. C01itEI~SS~6II 14. Reoresentative Daily Average Production or Iniect~on Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15 Attachments 16. Status of well classification as: Copies of Logs and Surveys run -- Oil X Gas Suspendedm Service Daily Report of Well Operations -- ~ -17. I hereby certify that the foregoing is true and correct to the best ot my Knowledge Slgned~'-'-° ,~- -- ~ Title ~J'~,~ ~>'~c~'- ~ .,c_~.,~ ,~.-~.-¢z. Date ~-z.f~ c, 1 4, Form 10-404 Rev ~/1~/~ SUBMIT IN DUPLICATE Shell Western E&P Inc. ~ 601 West Fifth Avenue · Suite 800 ~, ~ Anchorage, Alaska 99501 December 19, 1991 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Gentlemen: SUBJECT: SUBSEQUENT REPORT FOR MIDDLE GROUND SHOAL WELL C34-26; SUNDRY APPROVAL #91-214 Enclosed are duplicates of the Subsequent Report which cancels the proposed work to suspend well C34-26. C34-26 is an offset producer location to C24-26. C24-26 is currently being evaluated for conversion to injection. If you need additional reports or information, please contact Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, '/' R~.'C~. Blackburn Manager Alaska Operations Western Division RGB/SBBM/dlw Enclosures DEC ~ 0 199~ Alaska 0ii & 6as Cons. Anchorage SBBM~121991A.WP5 REPORT OF SUNDFIYLL OP£FIATION$ 1 Operations performed: Operation shutdown Pull tubing __ __ Stimulate Plugging __ Perforate __ Alter casingm Repair well ~ Other X .2. Name of Operator Shell Western E&P Inc. 3. Address 601 W. 5th Avenue, Suite 810 Anchorage, AK 99501 5. Type o1' Well: Development X Exploratory Stratigraphic 4 Location of well at surface At top of productive interval At effective depth At total depth Platform C, Leg 1, Conductor 3, 544.25'N end 1591.06'W of SE Corner of Sec. 23, T8N, R13W, SM Platform C, Leg 1, Conductor 3, 3894'S and 1769'W of SE Corner of Sec. 23, T8N, R13W, SM @ 4548'S and 1887'W of SE Corner of Sec. 23, T8N, R13W, SM 6. Datum elevation (DF or KB) 116' KB feet 7. Unit or Property name Middle Ground Shoal 8. Well Number C34-26 19. Permit number/approval number 68-0019/91-214 10. APl number 50-733-20093-00 11. Field/Pool MGS/"E", "F", & "G" Pools 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner 11,282 feet true vertical 9908 feet measured 11,024 feet true vertical 9692 feet Length Plugs (measured) Junk (measured) Size Cemented Measured depth True vertical depth 1732' 10-3/4", 40.5#, J-55 1500 sx 1732' 1642' 11,259' 7", 23-29#, N-80 1200 sx 11,259' 9889' Perforation depth: measured 9919'-11,000' (10 Intervals) true vertical 8720'-9672' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 EUE 8rd @ 10,683' Packers and SSSV (type and measured depth) Guiberson Uni-Vll @ 9880', 10,331', 10,481', 10,662'. Otis SSSV @ 290'. 13. Stimulation or cement squeeze summary ~ Intervals treated (measured) This procedure has been cancelled Treatment description including volumes used and final pressure DEC 20 1991 Alaska 0il & Gas Cons. Gomm~S$1O~ Anchorage 14, Pnor to well operation Subsequent to operation Od-Bbl Representative Daily Average Production or Iniection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments ] 16. Status of well classification as: Copies of Logs and Surveys run __ Ii Oil X Gas Suspended Service Daily Report of Well Operations m I ~ ~ m ,,, 17. I hereby certity that the torego~ng ~s true and correct to the best et my Knowledge Signed(~'-"-~v~ Title ~''Tg,-F.~ ~z,~o,-,.-~_.-r~.,., ~_...,,~,¢_.,,,,....t~ Date Form 10-404 Re SUBMIT IN DUPLICATE ( Shell Western E&P Inc. 601 West F~fth Avenue · Suite 800 Anchorage, Alaska 99501 August 28, 1991 Alaska Oil and Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen' SUBJECT: SUBMISSION OF THE APPLICATION FOR SUNDRY APPROVAL TO CONVERT MIDDLE GROUND SHOAL WELL NO. C34-26 TO AN INJECTION WELL Enclosed in triplicate is the application for sundry approval to convert Well No. C34-26 into a water injection well. The sundry operations are expected to begin September 1, 1991. If you have any questions, please call Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, V. . Ung~r Division Drilling Engineer Alaska Division VEU/slm Enclosures RECEIVED AUG 2 a 1991 ~ Oil & Gas Gons. Oom~tss't~n AOGCC\SUNDRY. DOC KAt STATE OF ALASKA I~ ALAS UIL AND GAS CONSERVATION COMMISSIO APPLICATION FOR SUNDRY APPROVAL R I [ I g L 1. Type of Request: Abandon Alter c,~sing Change approved program 2. Name of Operator Shell Western E&P Inc. 3. Address 601 West 5th Avenue, Suite 810 Anchorage, AK 99501 Suspend Oparal~on shutdown Re-enter suspended well Repair Well Plugging ~ Time extension Sl~mulate Pedorate Other X 6. Datum elevation (DF or KB~ 4. Location of well at surface At top of productive interval At effective depth At total depth Pull tubing __ Variance __ 5. Type o! Well: Development X Exploratory Stra~raphic Platform C, Leg 1, Conductor 3,541.65'N & 1596.41'W of SE corner of Sec. 23, T8N, R13W, SM Platform C, Leg 1, Conductor 3, 3,894'S & 1,769'W of SE corner of Sec. 23, T8N, R13W, SM. @ 4548'S & 1887'W from SE corner of Sec. 23, T8N, R13W, SM. 116' KB feet 7. Unit or Property name Middle Ground Shoal 8. Well number C34-26 9. Permit number 68-0019 10. APl number 50-733-20093-00 11. Field/Pool MGS/"E, F, & G" Pools .12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,282' feet 9908 feet 11,024' feet 9,692 feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural Conductor Surface 1,732' 10-3/4",40.5#,J-55 1,500sx Intermediate Production 11,259' 7",23-29#, N-80 1,200sx Liner Perforation depth: measured 9,919-11,000' (10 Intervals) true vertical 8,720'-9,672' Tubing (size, grade, and measured depth) 3-1/2", 9.34~, N-80 EUE 8rd @ 10,683' 2' Tubing tail wi"Q" Nipple Fish in bottom of hole Measured depth True vertical depth 1,732' 1,642' 11,259' 9,889' RECEIVED AU G 2 8 1991 Alaska Oil & Gas Cons. Comm'tsste[t N chomge Packers and SSSV (type and measured depth) Guiberson Uni-Vll @ 9880', 10,331', 10,481', 10,662'. Otis SSSV @ 290'. 13. Attachments Description summary of proposal X__ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 09/01191 115. Status of well classification as: Oil X Gas Suspended 16. If proposal was verbally approved -- ~ Service Conversion to Injection Name of approver Date approved 17. I hereby certify that the foregoing is true and correct to the best of my knowledge '.~P~3,igned Title Division Drilling/Production Engineer Date 08/28/91 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Tes.t_ Location clearance Mechanical Integrity Test_.~ Subsequent form requi"~d 10- Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE &PPLICATION FOR SUNDRY APPROVALS DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL WELL No. C34-26 CONVERT TO INJECTION WELL The Middle Ground Shoal well number C34-26 is currently shut in because of uneconomic productivity. The absence of injection on UNOCAL's Dillon Platform to the south, and our recently completed West Flank drilling program, has resulted in production withdrawals exceeding fluid replacement via waterflood injection. The following operations are proposed to convert this well to an injection well in compliance with Area Injection Order No. 9 and the AOGCC Regulations outlined in 20 AAC 25.412. Attached are illustrations of the current and proposed wellbore diagrams. PROPOSED OPERATIONS SUMMARY 1) RU Slickline, pull ball valve, and run 2.70" gauge ring/drift through the end of the tubing and tag PBTD. 2) Cut tubing at 10300' MD (22' above 2nd packer). 3) Punch tubing above top packer and kill well with Filtered Inlet Water (FIW) via the injection header. 4) Install and test 5000 psi BOP Equipment per API RP 53. 5) Pull tubing and top packer. 6) Dress off downhole tubing stub if necessary. 7) Run overshot guide and packer assembly on 3-1/2" injection tubing. 8) Reverse circulate inhibited FIW packer fluid. 9) MIT Pressure test tubing/casing annulus. 10) Release rig. 11) Install injection line and initiate injection. 12) Open additional pay in the "E", "F", and "G" pools to support offset production. RECEIVED AUG 2 8 1991 Alaska Oil & Gas Cons. Commissien ;Anchorage O ATTACHMENT I MGS C34-26 PRESENT STATUS 1~ BALL ~I~LVE at 290' 4' CONDUCTOR at 370' TOC (CALC) at 466'*/- 10-3/4' SURFACE CASING 0-1732' 40.6# J-66 DRIFT/ID TOC (CBL) at 7850./- GR-GS 9919' - 9967' HC-HD 10247' - 10305' HD-HE 10355' - 10866' HE-HF 10397' - 10463' HI_HK 10526' - 10540' HK-HN 10547' - 10644' EOT at 10683' HN-HR 10690' - 10785' HN-HR 10786' - 11000' NOTE: 2' TUBING TAIL w/'Q° NIPPLE FISH ON BOTTOM RRW/WAM/C3426PRE.CHT TD at 11282' GLM #1 at 2140' GLM #2 at 4121' GLM #3 at 6660' GLM #~. at 6912' GLM #~'at T966' GLM #l~at 8766' GLM #1 at 9401' GLM #~at 9886' 3-1/2' 9.8# N-80 TUBING from SURFACE to 10688' 'XO' SLIDING SLEEVE at 9841' UNIPACKER VII PACKER at 9872' GLM at 10278' 'XO' SLIDING SLEEVE at 10315' UNIPACKER VII at 10822' GLM at 10422' 'XO' SLIDING SLEEVE at 10459' UNIPACKER VII at 10475' GLM at 10604' 'XO' SLIDING SLEEVE at 10640' UNIPACKER VII at 10664' 'X' NIPPLE at 10673' 7' PRODUCTION CASING at 11398' 0-4711' 28# N-80 4711'-8646' 26# N-80 8646'-11269' 29# N-80 PBTD at 11024' 2.867' 2.750' 2.992' 2.750' 2.992' 2.750' 2.992' 2.760' 2.992' 2.750' RECEIVED AU 6 2 8 1991 Alask~L Oil & Gas Cons. '_Anchorage. O ATTACHMENT II OSNTAT MGS C34-26 PROPOSED US CONVERSION TO INJECTI L'X' NIPPLE lit 300' 24' CONDUCTOR al 310' TOC (CALC) at 466'*/- 10-3/4° SURFACE CASING 0-1732' 40.6# J-66 2.750' TOC (CBL) at 7850./- GR-GS 9919' - 9957' HC-ND 10247' - 10305' HD-HE 10355' - 10366' HE-HF 10397' o 10468' HI_HK 10526' - 10540' HK-HN 10547' - 10644' EOT at 10683' HN-HR 10690' - 10788' HN-HR 10786' - 11000' NOTE: 2' TUBING TAIL w/'Q' NIPPLE FISH ON BOTTOM RRW/WAM/C3426PPS.CHT TD at 11282' 3-1/2' 9.$# L-80 TUBING from SURFACE to 10300' 2.867' 'X' NIPPLE at 9770' BAKER 'FHL' RETRIEVABLE PACKER at 9800' 2.760' 3.000' 3AKER 'FHL' RETRIEVABLE PACKER at 10,100' 'X' NIPPLE at 10270' BAKER SBR GUIDE at 10300' 3-1/2' 9.3# N-80 TUBING at 10300' - 10663' 'XO' SLIDING SLEEVE at 10316' GUIBERSON UNIPACKER VII at 10322' GLM at 10422' · XO' SLIDING SLEEVE at 10469' GUIBERSON UNIPACKER VII at 10478' GLM at 10464' 'XO' SLIDING SLEEVE at 10469' GUIBERSON UNIPACKER VII at 10654' 'X' NIPPLE at 10673' 3.000' 2.750' 2.867' 2.760' 2.992' 2.760' 2.992' 2.750' 2.992' 2.750' 7' PRODUCTION CASING at ll398' 0-4711' 23# N-80 4711'-8646' 26# N-80 8646'-11269' 29# N-80 PBTD at 11024' RECEIVED AUG 2 8 1991 Alaska 0ii & Gas Cons. CommiSSiOn Anchorage ( Shell Western E&P Inc, 601 West F~fth Avenue · Suite 800 Anchorage, Alaska 99501 July 15, 1991 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen' RECEIVED JUL 1 ¥ 1.991 Oil & Gas Cons. SUBJECT' SUBMISSION OF APPLICATION FOR SUNDRY APPROVAL TO SUSPEND MIDDLE GROUND SHOAL WELL NO. C34-26 Enclosed in triplicate is the application for sundry approval to suspend Well No. C34-26. The well has no economic reserves remaining as a producer, however, the wellbore has future potential for one of the following applications: 1. Service well for disposal applications. 2. Injection well for Hemlock ("G" Pool) waterflood maintenance. 3. Slot recovery for future drilling location. We are requesting a variance from 20 AAC 25.105(k) which requires that the interval below the plug be filled with a fluid of a density that equals or exceeds the fluid density used to drill the interval. Well C34-26 was drilled in March/April of 1968 with a maximum mud weight of 9.9 ppg. However, the mud weighed 9.9 ppg as a result of inadequate solids control and not as a result of weighting up the mud to counteract pore pressure. All indications are C34-26 was normally pressured when drilled thus a hydrostatic column of seawater would equal or exceed the pore pressure when the well was drilled. The purpose of the variance is to prevent formation damage of the Hemlock from an overbalance condition so as to preserve the potential of Hemlock waterflood injectivity. We are also requesting exception to 20 AAC 25.110(c) which states "...the operator shall set a bridge plug between 200 and 300 feet below the casing head and cap with 100 linear feet of cement". This is requested to preserve the wellbore as much as possible for one of the applications listed above. As an alternative, we will monitor all casing and annular pressures daily and will notify the commission if any pressure exceeds 150 psi. ( If you have any questions, please call Mr. Paul Huckabee at {907) 263-9646 or Mr. Bill Miller at {907) 263-9633. Very Truly Yours, V. E. Unger Division Production Engineer Alaska Division VEU/WAM/PTH Enclosures cc: R. G. Blackburn W. F. Simpson R. G. Lippincott P. T. Huckabee S. M. Logan D. L. Marshall - Kenai SEA File 5.6120 C34-26 Correspondence Fi 1 e Reading File Product i on Fi 1 e A r,,A OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend__X Operat~3n shutdown __ Re-ente~ suspended well Alter casing __ Raper Well Plugging __ Time extension Stimulate -- Change approved program __ Pull tubing Variance Perforate __ Otter 5. type ot Well: 6. Datum elevation (DF or KB1 2. Name of Operator Shell Western E&P Inc. Development X 116' KB feet __ 3. Address 601 West 5th Avenue, Suite 810 Exploratory 7. Unit or Property name Anchorage, AK 99501 Stm~raphic __ Middle Ground Shoal Service 8. Well number 4. Location of well at Platform C, Leg 1, Conductor 3,541.65'N & 1596.41'W of SE C34-26 surface corner of Sec. 23, T8N, R13W, SM !9. Permit number At top of productive Platform C, Leg 1, Conductor 3, 3,894'8 & 1,769'W of SE corner of 68-0019 interval Sec. 23, T8N, R13W, SM. 10. APl number At effective depth 50-733-20093-00 11. Field/Pool At total depth @ 4548'S & 1887'W from SE corner of Sec. 23, T8N, R13W, SM. MGS/"E, F, & G" Pools "i"2. Present well condition summary Total depth: measured 11,282' feet Plugs (measured) true vertical 9908 feet Effective depth: measured 11,024' feet Junk (measured) 2' Tubing tall w/"Q" Nipple Fish in bottom true vertical 9,692 feet of hole Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1,732' 10-3/4",40.5#,J-55 1,500ex 1,732' 1,642' Intermediate Production 11,259' 7",23-29#,N-80 1,200ex 11,259' 9,889' Liner I;~EIVED Pedoration depth: measured 9,919-11,000' (10 Intervals) JUL 1 9 ]991 Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 EUE 8rd @ 10,683' ~,'~$ka .OJ.J & {]as C0115, Packers and SSSV (type and measured depth) Guiberson Uni-VII @ 9880', 10,331', 10,481', 10,662'. Offs SSSV @ 290'. 13. Attachments Description summary of proposal __ Detailed operations program X_~ BOP sketch 14. Estimated date for commencing operation 10/01/91 15. Status of well classification as: Oil X Gas Suspended 16. If proposal was verbally approved -- -- Service Name of approver Date approved 17. I hereby/certify that the foregoing is true and correct to the best of my knowledge Signed ~..~, (.~,~.~~,// Title DivisionDrllling/ProductionEngineer Date 07/15/91 N~oti FOR COMMISSION USE ONLY Conditions of approval: fy Commission so representative may witness IApproval No. / Plug integrity__ BOP Test Location clearance I Mechamcal Integrity Te. st__ --Subsequent form require'--d 10- Approved Gopy · Returned .~pproved by order o~hd ~:on~miss,on ~av~d~' dOhn$'~Oe Comm,ss,oner Date--/ ~.~ ~:l.I . Form 10-403 Rev 06/15/88 SUB~T IN ~IIPLIOATE MTDDLE GROUND SHOAL C34-26 TEMPORARY ABANDONMENT PROGNOSIS STATUS: C43-23 was originally drilled and completed in April, 1968 with an initial production rate of 1800 BOPD, 1% cut. After reaching a waterflood peak of 1400 BOPD in 1969, production declined at a rate of 22% per year. In January 1984, C34-26 was acidized using coiled tubing which resulted in a production increase of 50 BOPD, however the increase was only maintained for less than a year before it was back down to pre-acidized levels of 40 BOPD. The following year the well was acidized again and resulted in a 40 BOPD increase. Finally, in 1988, C34-26 was shut in due to 90% water cut and a dismal production rate of 27 BOPD. Additionally the well has experienced a long history of annular (tbg/csg) blockages which would require a rig workover to repair at an estimated cost of $250,000. This expenditure is not justified considering the marginally economic oil productivity potential and high water cut. OBJECTIVE: Temporarily abandon C34-26 (Conductor 3 in Leg 1) for future potential as a service well, Hemlock injector or for slot recovery to drill a future well. COST ALLOCATION: ATTACHMENTS: I II III PROCEDURE: Charge all costs to Work Order No. .i~ [~' IVED Present Status Fluid Backflow Handling Procedures JUL 1 cy ~ Proposed Status ~-a~ka O~.& Gas Cons. Cornn!_i$~lq~ '~"~~chora~ 1. Rig up slickline on wellhead. GIH with a 2.70" gauge ring to ensure tubing is clear to 10,400' so as to be prepared to cut tubing at 10,300'. Remove dummy valve in GLM #8 at 9835'. Be prepared to shoot eight 1/4" holes in tubing with Dia-Log tubing punch if dummy valve cannot be retrieved. [See step #3.] 2. Circulate a well volume of FIW through GLM #8 at 9835' MD (8639' TVD) taking returns through a choke to backflow system and then to the production handling facilities. Refer to Fluid Backflow Handling Procedures in Attachment II. Monitor shut-in pressures and determine the appropriate fluid density with which to kill the well. If necessary kill well. HGS C34-26 Temporary Abondonment 3. RU Dialog with lubricator while rig is on Leg 4. Test lubricator to 1500 psi. GIH with 2-5/8" jet tubing cutter and cut 3-1/2" tubing at 10300' (below the top packer and a maximum of 30' above the top HC-HD perf at 10,247' -reference Attachment I & III for mechanical configuration). RD Dialog. [This step should be performed in Step #1 if Dialog is rigged up to punch tubing.] Ensure well is static. 4. Move rig over well. Check tubing and casing pressure. Set 3" Type H BPV and remove tree. Give AOGCC 24 hours notice prior to testing BOP. Install and test BOP to 5000 psi. Pull BPV. 5. Pull out of hole with tubing, top Guiberson UniPacker VII packer and tubing tail. The lower three Guiberson UniPacker VII packers and the tubing between them will remain in the hole. 6. RIH with 3-1/2", 13.3#, X-95/S-135, IF drill pipe {DP) with a bottom hole assembly {BHA) including a 6" flat bottom mill, 2 boot "junk" baskets, and casing scraper. Check and ensure scraper inserts are secure. Clean through the GR-GS perfs from 9919' -9957~ and continue in hole to 10,250+/-. POOH. 7. GIH with a retrievable bridge plug (RBP) on 3-1/2" drill string and set RBP at 10200~+ {within 50' of the top HC-HD perfs). Dump a minimum of 250 lbs. sand to cover the RBP with a minimum of 10' of sand. Wait for sand to fall. Tag sand fill to ensure adequate coverage of retrieving neck. 8. Begin mixing and pumping 100 sx (22 bbls) Class "G" cement (15.8 ppg, 5.0 gal/sk, 1.15 cf/sk} and spot 100 sx of cement on top of the sand/RBP. Include a fresh water spacer in front and behind cement. Pull out 7+ stands and reverse out. Wait for cement to set for 8 hours. Estimated TOC at 9650'+/-. These plugs satisfy the requirements of 20 AAC 25.105(h)(1)(A)&(C). DP Capacity: Est. Job Time: Thickening Time: Time to Temp: BHST: 75.7 bbls 40 minutes - Assumes 5 BPM mixing and displacing 2 hours + 40 mi nutes 170 degrees F ~ 9000' TVD 9. Pressure test 7" casing and plug to 2300 psi for 30 minutes to ensure casing and plug integrity. Tag the TOC to record the actual location of the cement plug to satisfy 20 AAC 25.105(1). POOH. ( I, IGS C34-26 Temporary Abondonment 10. Install wellhead (consisting of master valve w/tree cap minimum) equipped with gauges to monitor 7" casing pressure and 7" x 10-3/4" annulus. Monitor casing and annulus pressures daily and report in the "Dai 1 y Product i on Report". WAM 7/9/91 6 7 8 9 10 11 12' 13 14 15 16 17 18 19 20 21 ATTACHMENT I COMPLETION EQUIPMENT DETAIL SHEET MGS C34-26 7/28/87 NO. ITEM 1. OTIS BALL VALVE 2. GAS LIFT MANDREL #1 3. GAS LIFT MANDREL #2 4. GAS LIFT MANDREL #3 5. GAS LIFT MANDREL #4 6. GAS LIFT MANDREL #5 7. GAS LIFT MANDREL #6 8. GAS LIFT MANDREL 9. GAS LIFT MANDREL #8 10. OTIS "XO" SLIDING SLEEVE 11. UNIPACKER VII 12. GAS LIFT MANDREL #9 13. OTIS "XO" SLIDING SLEEVE 14. UNIPACKER VII 15. GAS LIFT MANDREL #10 16. OTIS "XO" SLIDING SLEEVE 17. UNIPACKER VII 18. GAS LIFT MANDREL #11 19. OTIS "XO" SLIDING SLEEVE 20. UNIPACKER VII 21. OTIS "X" NIPPLE APPROXIMATE I'VD. MD. PSI OR 290 290 1988 2140 900 3/16 3686 4121 910 3/16 5022 5650 915 3/16 6121 6912 915 3/16 7018 7955 950 1/4 7701 8756 950 1/4 8257 9401 950 1/4 8639 9835 GX2??? 8645 9841 8679 988O 9030 10278 DUMMY 9062 1O314 9077 10331 9164 10428 DUMMY 9195 10463 9211 10481 9327 10610 DUMMY 9356 10644 9372 10662 9382 10673 9391 10683 (E.O.T.) CASING 10 3/4", 40.5#, J-55 @ 1732' w/1500 sx 7" 23-29#, N-80 @ 11259' w/1200 sx PBTD = 11,024' TD = 11,282' TUBING 3 1/2", 9.3#, N-80 EUE 8RD @ 10683' PERFORATED ZONE GROSS INTERVAL GR-GS 9919-9926' GR-GS 9932-9957' HC-HO 10247-10256' HC-HO 10284-10305' HO-HE 10355-10365' HE-HF 10397-10453' H[-HK 10526-10540' HK-HN 10547-10644' HK-HN 10690-10785' HN-HR 10786-11000' NOTE: 2' TUBING TAIL w/"Q" NIPPLE FISH IN BOTTOM OF HOLE ( ( ATTACHMENT No. 2 PROCEDURES FOR HANDLING BACKFLOWED AND CIRCULATED FLUIDS Ail backflowed and circulated fluids must be routed through the backflow separator prior to being sent to the Onshore Facility for discharge. Emulsion breaker should be added as required. Bottle testing is recommended to determine the concentration of breaker. Monitor fluids for H2S and add appropriate scavenging chemicals as required. To satisfy EPA requirements, if the amount of fluid exceeds 250 bbls at one time, the Onshore Operator must take samples of all completion and/or well treatment fluids at the onshore discharge line. Samples must be sent to C&G labs in Anchorage for oil/grease and pH analysis. The Onshore Operator should label samples with description of fluid and date, such as: "Circulation returns from C34-26 workover - dated 10/xx/91". Notify Onshore Operator when the fluid is being sent. Use the following calculation to determine when the samples need to be caught. Pipeline 2660 bbl Delay = ............................ x 24 hrs = Gross Daily Prod "C" (bbl) + Workover fluid slug (bbl) Onshore Facility Delay = 1000 bbl Gross Daily Prod "A" "C" and "Baker" (bbl) hfs x 24 hrs = hrs Total time between slug shipment and sample time = hfs NOTE: Because the operations may result in a significant quantity of contaminated return fluids, the Onshore Operator should be notified and prepared to divert the transferred fluid to a holding tank. This will allow further dilution and processing of any contaminated fluid prior to processing through the plant for discharge. O ATTACHMENT III TS MGS C34-26RD PROPOSED TATUS TEMPORARY ABONDONMEN TOC (CBL) at 7850+/- TOC (PROPOSED) at 9660' TYONEK PERFORATIONS: GR-GS 9919' - 9957' 8POT 10' SAND & 100 ax 'G' on top RETRIEVABLE BRIDGE PLUG RETRIEVABLE BRIDGE PLUG at 10200'* HEMLOCK PERFORATIONS: HC-HD 10247' - 10306' HD-HD 10355' - 10365' GUIBERSON UNIPACKER VII at 10331' HE-HF 10397' - 10463' HD-HF 10355' - 10365' PERFORATIONS: 10247'-11000' HI_HK 10526' - 10540' HK-HN 10547' - 10786' GUIBERSON UNIPACKER VII at 10481' HN-HR R RW/~I~M/C 3426P PS.CH T EOT at 10683' TD at 11,282' GUIBERSON UNIPACKER VII at 10662' 7' PRODUCTION CASING at 11282' 0-4711' 23# N-80 4711'-8646' 26# N-80 8646'-11269' 29# N-80 ( Shell Western E&P Inc. O 601 West Fmfth Avenue * Suite 800 Anchorage, Alaska 99501 June 11, 1990 Alaska Oil and Gas Conservation Commission ATTN: Elaine Johnson 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: TRANSMITTAL OF REQUESTED INFORMATION REGARDING THE SWEPI OPERATED MIDDLE GROUND SHOAL FIELD Dear Ms. Johnson' In a recent telephone conversation you discussed with Ms. Susan Brown-Maunder information that would be helpful to you if we could provide it. Enclosed, for your convenience and use, are the following' 2 location surveys showing the location of Platform A 1 list of conductor/well locations (in relation to the SE corner of Sec. 11, TBN, R13W) for Platform A wells 1 location survey showing the location of Platform C I list of conductor/well locations (in relation to the SE corner of Sec. 23, TSN, R13W) for Platform C wells In addition you requested a revised copy of the Well Completion or Recompletion Report and Log (10-407) for the recently completed well C21-23. The well location at the top of the producing interval and the well location at total depth as been changed to reflect the actual surveyed location. If you have any further questions regarding these matters, please continue to contact Susan Brown-Maunder at (907) 263-9613. Very Truly/Yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/vj Enclosures cc: Susan Elsenbast-AOGCC \LETTERS\AOGCC\061190. DOC RECEIVED JUN 1 I990 0il & ~,a~ Corn;. Comm[;;,~l~ Anchoraga PLATFORM "C" MIDDLE GROUND SHOAL CONDUCTOR/WELL SURFACE LOCATIONS LEG 1 Centered 541.65 ft. North and 1596.41 ft. West of the SE Corner of Sec. 23, TSN, R13W, SM. CONDUCTOR WELL LEG 2 DISTANCE FROM SE CORNER NORTH WEST 1 C23-23 547.10 1599.00 2 C32-23 547.25 1594.46 3 C34-26 544.25 1591.06 4 C24-26RD 540.57 1590.68 5 C31-26 536.91 1593.01 6 C34-23 535.88 1597.22 7 C23-26 538.03 1600.98 8 C22-26RD 542.18 1602.22 CONDUCTOR LEG 3 9 10 11 12 13 14 15 16 LEG 4 CONDUCTOR 25 26 27 28 29 30 31 32 Centered 618.65 ft. North and 1549.76 ft. West of the SE Corner of Sec. 23, TSN, R13W, SM. WELL DISTANCE FROM SE CORNER NORTH WEST C22-23 623.65 1552.66 C24A-14 624.15 1548.36 C43-14 622.65 1544.76 C41-26 618.25 1543.86 C21-23 613.85 1546.26 C21-26 612.65 1550.46 C24A-23 614.85 1554.26 C13-23 619.].5 1555.66 Centered 582.42 ft. North and 1489.90 ft. West of the SE Corner of Sec. 23, TSN, R13W, SM. Centered 505.41 ft. North and 1536.56 ft. West of the SE Corner of Sec. 23, T8N, R13W, SM. WELL DISTANCE FROM SE CORNER NORTH WEST C42-23 C31-23 C43-23 C41-23 C33-26 C-LINE C44-14RD C24-23 509.00 1541.00 509.81 1536.57 507.65 1532.61 503.51 1531.56 499.00 1534.44 498.37 1538.72 500.87 1542.26 505.12 1543.10 DISTANCE FROM CENTER OF LEG N/S E/W 5.45 -2.59 5.60 1.95 2.60 5.35 -1.08 5.73 -4.74 3.40 -5.77 -0.81 -3.62 -4.57 0.53 -5.81 DISTANCE FROM CENTER OF LEG N/S E/W 5.00 -2.90 5.50 1.40 4.00 5.00 -0.40 5.90 -4.80 3.5O -6.00 -O.70 -3.80 -4.50 0.50 -5.90 DISTANCE FROM CENTER OF LEG N/S E/W 3.59 -4.44 4.40 -0.01 2.24 3.95 -1.90 5.00 -6.41 2.12 -7.04 -2.16 -4.54 -5.70 -0.29 -6.54 e x~ MEMORAND JM State(of Alaska ALASKA OIL AND ~AS CONSERVATION COI~II~SION TO: Lonnie C. Smithf,~/ Commissioner DATE' August 8, 1988 FILE NO: D. BDF. 008 THRU. Michael T. Minder Sr. Petroleum Engineer TELEPHONE NO: SUBJECT: Safety Valve Tests Shell-MGSU Platform C MGS Oil Pools / FROM: B obbyD. Foster~--~~, Petroleum Inspector Thursday, August 4, 1988.. The tests began at 7~30 a.m. and were concluded at 10..3~' a.m. With 10 Pilots, 10 $SSV s and 10 SSV's tested. As the attached Safety Valve Test Report shows one SSSV's failed. This.~will be repaired and the AOGCC Office notified. · ,Comment by Hike Minder~ Richard Vickerson called August 8, 1988, to 'notify Co_mmission that the SSSV in C42-23 has been replaced and ,, tested OK. L Attachment Pilots Tested 10 Pilots Failed SSSV's Tested 10 SSSVIO Failed SSV's Tested 10 SSV's Failed 02-001A (Rev 8185) AOGCC SAFETY VALVE TEST REPORT PAGE PRESSURES - PSIG {FIELD: MIDDLE GROUND SHOAL OPERATOR: SHELL WESTERN E&P ] WELL PERMIT i SV TST ] PILOT [ NUHBER ] C44-14RD JC-23-23 I NUMBER 77-0079-0 68-0030-0 ]C-31-23 68-0069-0 IC-32-23f 75-0035-0 IC-42-23 / 78-0024-0 IC-43-23/ 68-0060-0 ]C22-26RI~ 76-0065-0 IC24-26RI~ 79-0062-0 ~C-31-26 67-0063-0 IC'34-26 / 68-0019-0 J / DUE LOW ) ~~/~ ~/~ __~/P __I,/q REMARKS: SHELL C PLATFORM FLG ] SI ] SSV Issvl,, sssv ] FP ] FP { ~]~ I I I DATE: o [ I I __lssslNI ITSTI ]P ITSTITI I~1 I .... I_1 INSPECTOR I I · I~o IF.,_, I I t,4'1 I~1, I_1 I I , I~-o IF_F_I l~o I_1 ,, , May 31, 1985 Shell Westem E(&P Inc. 0 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: ~-j~ 3-~t% ~ Please find the~enclosed Sundry Notices for work that is schedurled to begin around.J~.lO, 1985, on three of our Middle Ground.Shoal wells. The wells are-all~n Platform C, C22-26, C34-26, and C42-23 A written approval is requested at your earliest convenience. V/~;tr ly yours, Sr Sta' Environmental Engineer Pacifi 'ronti Division SBB/ch Enclosure RECEIVED JUN 1 7 1985 Alaska 0~1 & Gas Cons. Commission Anchorage "(j STATE OF ALASKA (~',vl ALASKA IL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator Shell Western E & P Inc. 3 Address 601 West Fifth Avenue, Suite 810; Anchora.qe, AK 4 Location of Well at surface' 99501 Conductor 3, Leg I @ 3.17'N & 4.89'E from center leg I @ 541.65'N & 1596.41'W of SE corner of Sec. 23, Twsp 8N, Rge 13W. SM 5. Elevation in feet (ind~cate KB, DF, etc) 116'KB 6 Lease Designation and Serial No ADL 18756 12 7 Permit No 68-0019 8 APl Number 5o- 133-20093 9 Umt or Lease Name Middle Cround Shoal 10 Well Number C 34-26 11 Field and Pool Middle Ground Shoal "G" Pool Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF' (Submit in Tr~plmate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other )~ Pulhng Tubing [] (Note Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent details and g~ve pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Please see attached prognosis for details on the acid wash. 141 here~~t/~;~olng is Signed The s~;l~ f:~m,ss,~n use Condmons of Ap~l, ~f any RECEIVED JUN 1 ? i985 A~aska O,i & Gas Cons. Commission Anc~orage and correct to the best of my knowledge T,t~eSr. Staff Environmental Enq. Date 6-04-85 Approved by COMMISSIONER Approved Cop,/ Returned By Order of the Comm~sston Date Form 10-403 Rev 7-1-80 Submit "Intentions" in Tr,phcate and "Subsequent Reports" ~n Duphcate ~ID 6TINULATION C34-~ #IDD~ 6ROUND 6HD~ FIB-D STATUS: Idel I Bas I irt i~ 48 BDO, l~e 6~oss. I[CH~IC~L IX~?AIL$: See attached sche~Jtic. PURPO~: ~cidize with coiled tubing. 1. Rig up wireline. Test lubricator to 35e9 psi. Pull b~ll valve. I~ke drift run to bottom and ~eco~d depth. POOH and rig dow~. 2. #IRU coiled tubing and acid equilxlent. Test lines, t~ee and coiled tubing to 5em2 psi. Test hydraulic system and BOP. Test acid compatibility by lixing acid with p~duced fluid sample and note any foTllation of sludge. Filter all fluids through a 2 micro, r, filter. Shut Nell in. 3. RIH with coiled tubing ~hile pumping 3~ ~Jmonium chloride solution at minimum rate. #ith coiled tubing stat io~ar¥ le' above PBTI) (or fi 11 depth), pump ~e BBLS of 3~ amonium chloride solution to fill casing &c~oss zone. FolloN &~onium chloride with the following t~eat~nt: ST~ I~UID V[X.~ 1. Xylene Solvent 5e~ gal a. le~ HCI 5e~ gal 3. 7 1/8 I 1/8 Ieee gal i4her, acid is at the end of the coiled tubing, have coiled tubing located at the botto~ perf (ll,ee~'). pusp t~eat~ent at 1/4 Bbl per minute. #ake one pass with coiled tubing across interval (llvee~' -le~Te~,) during each stage of acid treatment. FolloM acid with ~e Bbls ~ ~m~onium chloride. 14hen a~Bonium chloride is at the end of the coiled tubing have tubing located lO' above PBTD (or fill depth) 5. Place ~el] on p~oduction. Pump an additional coiled tubing volume of mmonium chloride to displace ( use diesel if ~eather or transportation dictate). PO0~. RECEIVED JUN i ? i9 5 Alaska OJ[ & Gas Cons. Commission Anchorag~ C ~4-Z6 -) Item 1 2 3 4 6 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 I)escrtptlon 3 1/2" Otis Ball Valve 3 1/2" ICBX ~ndrel 3/16" 900 3 1/2" ICBX ~ndrel 3/16" 910 3 1/2" ~ Itandrel 3/16' 915 3 1/2' ICBN 14andre1 3/16" 915 3 1/2" ICBX Itandrel 1/4' 950 3 1/2" ICBX Itandrel 1/4' 950 3 1/2" ICBIq Iqandrel 1/4"960 3 1/2" IC&q Flandrel GX2 3 1/2" Otis X-O Sleeve Untpacker VII 7' X 3 112' 3 1/2' ICeX Iqandrel 3 1/2' Otis X-O Sleeve Untpacker VI! 7" X 3 1/2" 3 1/2" ICBX Itandrel 3 112" Otis X-O Sleeve Untpacker VI! 7' X 3 1/2" 3 1/2" KB# Handrel 3 1/2' Otis X-O Sleeve Untpacker VIZ 7" X 3 1/2" 3 1/2' Otts X-Nipple - 290 2140 4121 NOTE: 12-31-81 5650 Changed out GLV's 6912 1-7 per RYH 7955 8756 9401 9835 g841 g880 10278 10314 10331 10428 10463 10481 10610 10644 10662 10673 10683 £.O.T. Perforations GR-GS HC-HD HD-H£ H£-HF HZ-HK HK-HN HH-HR 9919- 9926 10247-10266 10355-10365 10397-10453 10520-10540 10547-10644 10786-10864 10912-10941 9932- 9957 10284-10305 10690-10752 10884-10902 10962-10994 ~perforations 12-5-76 HK-HN(L) 10700-10752 HN-.R(U) ]Oe30- OSSS HH-HR(L) 10885-11000 JUN ! 7 19[~,~ Alaska 0]1 & Gas Cons. Commission Anchorage 2 ft. + Tubing Tail w/Q Nipple Fish in bottom of hole PBTD. -11213 Btm Cs9 11260 Page 105 February 23, 1984 Shell Western E&P Inc. A Subs~d~aryol Shell 0~1 Company 200 N Dairy Ashford P O Box 527 Houston, TX 77079 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Chatterton: Enclosed for your information are the following eleven reports submitted in duplicate: Middle Ground Shoal Field Well No. A12A-01 Monthly Report of Drilling Operations Sundry Notice-Subsequent Report of Perforations & Stimulation Well Completion Report Middle Ground Shoal Field Well No. C24-26RD Sundry Notice-Subsequent Report of Stimulation Middle Ground Shoal Field Well No. C34-26 Sundry Notice-Subsequent Report of Stimulation Middle Ground Shoal Field Well No. A13-12RD Sundry Notice-Subsequent Report of Stimulation Seal Island Wildcat Well BF-47#1 Monthly Report of Drilling Operations Sundry Notice-Subsequent Report of Perforations & Testing Sundry Notice-Subsequent Report of Abandonment Well Completion Report Seal Island Wildcat Well OCS Y-181 #1 Sundry Notice-Notice of Intention to Change Plans (in triplicate) Please maintain the confidentiality of this information. RGH: mh Attachments Yours very t.ruly, R. G. Hollis Manager Production Administration Pacific Frontier D v E£EiVEB -FEB STATE OF ALASKA ALASKA('_ ,L AND'GAS CONSERVATION C~ ,1MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL EX OTHER [] 2. Name of Operator Shell Western E&P, [nc. 3 Addres~ 601 West 5th St., #810, Anchorage, AK 99501 4. Location of Well Conductor 3, Leg I @ 3.17'N & 4.89' E from Center Leg 1 @ 541.65'N & 1596.41'W from SE Corner Sec. 23, T8N, R13W, S.M. 5. Elevation in feet (ind,:ate KB, DF, etc.) 105' DF 6 Lease Designation and Serial No. ADL 18756 7. Permit No. 68-19 8. APl Number so- 733-20093-00 9. Unit or Lease Name MGS 10. Well Number C 34-26 11. Field and Pool Middle Ground Shoal 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit m Duplicate) Perforate [] Alter Cas,ng [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation )'~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [-1 Other [] Pulhng Tubmng [] (Note. Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent deta,ls and g~ve pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Proposal: Acid Stimulate 1/15/84 Rigged up CTU. Ran in and spotted 500 gal xylene, 1000 gal 10% HCL, 2000 gal Mud Acid, and 1000 gal 10% HCL. POOH ,1/16/84 POOH Rigged down & released crews. RTP.~/~ RECEIVED 14. I hereby certify that l~he foregoing IS true and correct to the best of my knowledge. Signed ._ T,tle Div. Prod. Adm. Mgr. The space below for Commission use Conditions of Approval, if any Date 2/9/84 Approvad by By Order of COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-14~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ( STATE OF ALASKA C~ ALASKA OIL AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator Shel 1 0i 1 Company 3 Address Wayne Simpson, 601 Uest 5th St_= #RlO~ Anc__horage~ _A_K 4 Location of Well 99501 Conductor 3, Leg i @ 3.17' N & 4.89' E from Center Leg I @ 541.65' N & 1596.41' ~'J from SE Corner Sec. 23, T8N, R13W, S.M. 5. Elevat,on m feet find~cate KB, DF, etc ) 105' DF 12 I 6 Lease Designation and Serial No ADL 18756 7 Permit No 68-19 8. APl Number 50- 733-20093-00 9. Umt or Lease Name MGS 10 Well Number C 34-26 1 1 Field and Pool Middle Ground Shoal Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO. SUBSEQUENT REPORT OF. (Submit ~n Tr~phcate) (Submit m Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casmg [] Stimulate [~ Abandon [] Stimulation [] Abandonment [] Repmr Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing [] (Note Report muluple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) See attached. Subsequent Work Reported RECEIVED JAN 1 9 1984 Alaska 0il & Gas Cons. Commission Anchorage Signed14 I hereby i/1~t~olng., is true and correct to the beStTitleOfHgr.mY knowledgeprod. Adm, The space below for Commission use Date 1/4/84 Conditions of Approval, if any ORIGINAL Approved by. BT LONfll[ C. $~llftl COMMISSIONER Approved Copy Returned !-,2-,o - o° ¢__ . By Order of the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" ~n Duplicate Acid Stimulate C34-26 Platform C Middle Ground Shoal Field Status: Well gas lifting 104 Gross, 5% cut. Mechanical Details: See attached schematic. Purpose: Acidize with coiled tubing. Procedure: 5 Rig up wireline. Test lubricator to 3500 psi. Make drift run to bottom and record depth. P.O.O.H. and ri§ down. e Shut well in for 12 hours prior to acidizing. M.I.R.U. coiled tubing and acidizing equipment. Test lines, tree and coiled tubing to 5000 psi. Test hydraulic system and B.O.P. Test acid concentrations and compatibility according to acid test procedure. Filter all fluids through a 2 micron filter. e R.I.H. with coiled tubing while pumping diesel at minimum rate to 11,000' Pump following acid treatment. Stage Fluid Volume I Xylene Solvent 500 gal. 2 10% HC 1 1000 gal. 3 7½% 1½% HC1 HF 2000 gal. 4 10% HC 1 1000 gal. Pump treatment at ¼ Bbl per minute. Move coiled tubing across entire interval (11,000'-10,700') during each stage of acid treatment. e Displace acid to end of coil with diesel. Over displace by 5 Bbls to flush coil. P.O.O.H. Rig down. e Place well on production. Obtain good 12-hour production test after well cleans up. Approved ~ ~ ' Date ///~/~¥ Alaska 0il & Gas Cons, Oornrnisaion A.~chorage lo 2. 3. 4. 5. 6. 7. 8. 9. 10. Cost Estimate C34-26 Coiled Tubing Acidization Fill Clean Out 500 gal. Xylene 2000 gal. 10% HC1 Acid Additives 2000 gal. 7½-1½ HC1-HF Pump i day Tanks I day Lines I day Personnel I day Coiled Tubing Mi scel 1 aneous $ 2,500 2,000 800 2.400 2,000 8O0 1,600 3,600 8,000 2,000 Total $24,700 + 10% Contingencies $27,000 Fluid Additives Composition 10% HC1 0.3% W-35 (antisludge) 14 lbs/lO00 gal L-41 (iron sequestering agent) 1.2% A-200 (inhibitor) 7½%-1½% HC1-HF 0.6% W-35 0.4% W-52 (de-emulsifier) 14 lbs/lO0 gal L-41 0.8% A-200 RECEIVED JAN 1 91984 Alaska Oil & Gas Cons. CommissjoD Anchorage DATUM 34' 4 5 C 34 - 26 I~tem # Description 8. 9. 10. ll. 12. 13. 14. 15. 16. 17. 18. 19., 20. 21. 1. 3½" Otis Ball Valve 2.. 3½" KBM Mandrel 3/16" 900 3. 3½" KBM Mandrel 3/16" 910 4. 3½" KBM Mandrel 3/16" 915 5. 3½" KBM Mandrel 3/16" 915 6. 3½" KBM Mandrel 1/4" 950 3½" KBM Mandrel 1/4" 950 3½" KBM Mandrel 1/4" 950 3½" KBM Mandrel GX2 3~" Otis X-O Sleeve Uni-Packer VII 7" X 3¥ 3½" KBM Mandrel 3½" Otis X-O Sleeve Uni-Packer VII 7" X 3½" 3½" KBM Mandrel 3½" Otis X-O Sleeve Uni-Packer VII 7" X 3½" 3½" KBM Mandrel 3½" Otis X-O S1 eeve Uni-Packer VII 7" X 3½" 3½" Otis X-Nipple GR-GS HC'-HD HD-HE HE-HF HI-HK HK-HN HN-HR 290 2140 4121 5650 6912 .. 7955 8756 9401 9835 9841 9880 10,278 10,314 10,331 10,428 10,463 10,481 lO,610 10,644 10,662 10,673 10,683 E.O.T. Perforations 9919-9926 9932-9957 10247-10256 10284-10305 10355-10365 10397-10453 10520-10540 10547-10644 10690-10752 10786-10864 10884-10902 10912-10941 10962-10994 .Reperforati ons 12-5-76 HK-HN(L) 10700-10752 HN-HR(U) 10830-10885 HN-HR(L) 10885-11000 Note. 12-31-81 Changed.out GLV's I thru 7.~er RVH JAN 1 91984 Alaska 0~ & Gas Oons. Commission Anchorage 2 Ft. +- Tubing Tail w/Q-Nipple Fish in bottom of hole. PBTD 1 l, 213 BTM CSG ll ,260 Page 105 WELL ~4-26 PLATFORM C 5OO 4O0 300 200 100 Legend GROSS CLEAN ,~o,, 1983 WESTERN E&P OPERATIONS I'/IIDDLE GROUND SHOAL FIELD SHELL-ATLANTIC-STANDARD ,+ SiS iii PafS$ POS 1144! ADL 11756 S]21k. INJECTION WELL · PRODUCING WELL + P.A. PLUGGED & ABND. Fo~' C_. ) 7-0 w. F. SIMPSON SHELL OIL COMPANY 430 7TH AVENUE ANCHORAGE, ALASKA 99501 May 13, 1968 RECEIVED M/~Y 1. 4 lg68 DIVISION OF MINES & M, INEEA~ Confidential Material STATE OF ALASKA Division of Mines & Minerals 3001 Porcupine Drive Anchorage, Alaska Attention T.R. Marshall, Jr. Gent lemen: Attached are two copies of the Well Completion Report for our SAS Middle Ground Shoal C-34-26. Included with the report are the follow- ing data: Composite Log (Sepia and Print) Directional Survey (2) Well History (2) WCH/mw Very truly yours, R.D. Allen Division Exploitation Engineer Attachments Form P--7 st ructlonb on OIL AND GAS CONSERVA~ON C~~ 1968 reve, se s,de, WELL COMPLETION OR RECOMPLET O a ' b TYPE OF COMP~ON: WELL ~ Ol ~R ~ DEEP- BACK ~ DIFF nESVg ~ Other 2 NAME OF OPERATOR Shell Oil Co~y 430 Se~nch Avenue~ ~chor~ep Alas~ 99501 ~ LOCATION Og W~LL (Re~rt lo~tion clear]~ and ia accordance with any Etate requirements)* tt~ac~ ~onducCor 3~ It toy pron. ~nte,a~ r~rt~a ~ 9919~ (87~4 ~D) ~37~.7~'~ & ~778.64~ ~2~2~ (9907~ ~) 728.29~H & ~905,32~ ffrom ~E ~orner~ x~ ~~o 3-5-68 4-12-68 .4-16-68 ,. ! 106' D.F. ~LL~. . , - 11:282 ~, (9907 ~ 11:213~ ~ (9847 T 11:282~ - ~, PRODUCING ~'A'~V~(S), OF ~IS ~P~'~'~~,' ~M, ~E (~ AND ~)* ~,'W~ DI~ON~ E Pool 9919' QT!A' ~) [ su~v~~ 5. AP1 i%TUMEI%ICAL CODE 50-133- 200 93 s. Lm~s- DES~G~'~ON AN~ S~X~L NO ?, IF INDLa._~, AIJ.~'l-raa~ OR TlR/BE NAME None 8, UNIT,F2uRI~ OR LEASE Middle Ground Shoal 9. Wm~ NO C-34-26 10 '~',m,.r~'A~rD POOL, OR ~T Middle Ground Shoa 1 1~ ~, T, R, M, (~M O~~) Sec. 26, T8N, R13W, S.M. i DILt. BHC Sonic - CASING SI~E }* - - CA~ ~RD (Rel~rt all Itrings set in we'{l) HOLE SIZE ~lJ I II 3~ m j C~~G R~.COm~ ! Ai~IOUNT PUT LINER RECORD SIZE ;top (MD) BOTTO~ (mD) SACKS ~q~VI~T* 27 SCREEN (MD) SIZE TUBING 1~.1~OO1%D DEI:'TH S~T (MD) [ PACKER SET (~) 9779' 28 PERFORATIONS OPF~N TO , (Interval, s~ze and number) Perforated w/4- 1/2" jets/ft- 9919-9926~ 9932-9957~ 10,247-10,256, !0,284-10,305', 10,3-55-10,365, 10,397-10,453, 10,526-10,540, 547-10,644', t0,~690-10,752, 10,786-10,- 10,884-10,902, 10,912-10,941, 10,962-10 29 ACID, SHOT, F~RA~C'I'URE, CF2V~NT SQUICEZE, ETC , Dli~'~l'l{ I/N-TERVAL (MD) ANiOUNT ~'dVD KIND O,F MATE.R/AL USED .30. PRODU (;rloN D*A. TE FIRST PRODUCTION I PRODUCTION ME'II{OD (Flown~g, gas hi, t, pump.g--sEe and type of pump) 68 ~ Gas Lift D&T[ OF T~-8~, I-~OU~S TF~'I'~D CROI~iE SIZE [PROD'N FOR OLL---BEL 21-68 24 'I-Iro /64" tTEsr~ I 1968 I~ 689 CALCULA'riuo OIL--BBL. GAS--1V~CF FRESS 24-I-IOUR RATE Psi ~75 Psi - > i8 689 DISPOSITION OF GAS (~0ld. ~Sed for, ~eated, ere ) :d 32. LIST OF ATTACHMENTS SIGNED WELL STATUS (Producu~ or Snut,-,n) Producing WATER--~SL I G~-om ~o 124 ] 315 WA~B~ [ O~ G~VITY-~ (C~) ] 34.3' TEST WITNESSED . r, Print), History, Directional Survey (~2 copies) cert~~./~~/~_d information ts complete and' correct as aeterm£ned from all'available records /ff///'~-~~ ~I?L~Diw. ExplOitation Engineer DAWm ~/~ff' s 9 ~ *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General Th~s form is designed for submitting a,,complete and correct well completion report and log on all types of I~nzls and leases ~n Alaska Item: 16: Indicate which elevation ~s used as reference (where not otherwise sho~vn) for depth measure- merits g~ven ~n cther sp~aces on th~s form affd ~n any attachments Items 20, and 22:: If tl~s well ~s completed for sep~ratc production from more than "one ~nterval zone (multiple complenon), so state ~n ~tem 20, and ~n ~tem. 22 show the prcJuc~ng ~,nterval, or ~ntervals, top(s), bottom(s) ~nd n~me (s) 0f ~ny) fo'r Only the ~nterv¢~l reported ~n ~tem 30 Subm~! ~ separate rep. orr (page)" on th~s form, ~dequ~t~ly ~denn~ed, for e~ch ~d6~t~onal ~nte~val to be sel::fer~tely produce<J, show- ~ng the ac~lmonal d~ta. pertinent to such ~nterv~l Item26: "Sacks Cem~ent": Attached supplemental records for th~s well shoulJ show the' details of any'n%l- tiple stage cement.rig and the location of the cementing tool ., ,! Item 28: Submit ~ separate completion report on this form for each ~nterval to be sep~retely produced (See ~nstrucnon fo,r ~tems 20, and 22 ~bove) ¥IMA. P,,¥ OF [POH1VIATION TESTS IN( LUI)IM(~ IN~RVAb F~TED PH~UR~ DATA ~ ~COVEI~I~ OF OIL', GAS 35 G~GIC WAT~ AND MUD ~:: ~ E Pool 9,544 8382 . ~ - ~ - F Pool 9,919 8714 -- G Pool 10,247 9002 OR~} D~TA, A~CII B~IE~ D~C~I~O~S O~ LIPIlOLOGY[ POROSITY, FIIAC~R~ AP~W DIPS J '~ ~ND DEP~CT~D SH.OWS O~ O1~, G~ OR W~ o ,, R~.lease Date 5-16-.70 _ State of Alaska Department of Natural Resources DIVISION OF MINES AND MINERALS Petroleum Branch Area INDIVIDUAL WELL RECORD Location se:. (23) 26 , _ T .... 8N R. 13W .... S .Meridian Permit No. _68-19 _ CQnd. 3, Leg 1 & ~. 89E fr :--C-Leg 1 (Surface)__~44.8 FS.L & 1591.5 FEL: Sme. 9~ __ LoC. (Bottom) 500' FSL & 1880' FEL,.Sec. 26 MGS Drilling ceased 4~!2-68 Abandoned Operator~ Shell 0tl Co. Lease No.--ADL 18'756 or Owner Middle Ground Shoal Well No. . .C,34-26 Spud Date 3-5-68 Suspended IP_ 19&~ B/D, Completed ~-GL-~Y_ ._ 4-16,68 _ PBD 11,213 Total Depth .... 1!,282' Elevation 105' D.F. 9779' on pckr.. Gas__ 689 .... Casing: Size Depth 10 3/4~-40.5# 1732' 7"-23-26 & 29~ 11,259' 3%" tbg. 9848' Gray 4__~9~__API Cut ~/~__% psi, TP .... ._100 psi Bean,~!28:_/64 CP 875 Sx Cat Perf: 9919'-26'.;.9932'- 5 7 '; 10,247 ' -5 6 '; 10,28,4' -305 1500 ~10,355 '-.65'; 10,.397'-4~3' 10,526'-40' ;10,547'-644' 1200 10,690'-752' ;10,786'-864'; 10,884; 10,9~2'-94' Plugs: GEOLOGIC FORMATIONS Surface _~ Lo. west, T~s,ted~_ Hemlock Hemlock (F&G) WELL STATUS Ye ~r Jan Feb Mar Ap r May June July PRODUCTIVE HORIZONS Dept~.. ....... Contents 9919 '-10,994' , Oil Aug Sept Oct Nov Dec Remarks: Contractor: Santa Fe Drilling Co. PO'4A (Rev. 5-63) ,intea m U.S.A. S.[..]]~Z,,T, OTI.. ~~ (' Middle Ground Shoal - [ fi ElY [ ¢ Sec. ~ena~ ~cb 29~ 1968 MAY ] 4 1968 ' c. I~A¥ DEFVI'HS DIVISION OF MINES & MINERALS RF. MAR~ ~d,,IC..,HOPakOE ItROM I · Surface Location: Conductor 3, 3.17'N & 4.89'E from center Leg 1, 541.65'N & 1596.41'W from SE corner, Section 23, TSN, R13W, S.M. Elevation: 105' Derrick Floor ~LW) 1968 March 5-7 400 1,752 Spudded 11:00 A.M., 3-5-68~ Drilled 15" hole to 1752'. ~rbo #1 415-921, faced N57E Circulated to run casing. 8 1,752 1,836~ ~N~D 10-3/4" ~SING AT 1732' ~TH 1500 SACKS. Ran 10-3/4", 40.5~, J-55 Buttress casing with Baker guide shoe at 1732' and Baker flex-flow fill-up collar at 1691'. Cemented with 100 cuft inlet water ahead of 1300 sacks class "G" cement m~ed with 1950 cuft inlet water containing 3200 lbs of gel. Followed gel cement with 200 sacks class "G" cement m~ed with inlet water. Displaced cement with 980 cuft mud. Bumped plug with 1000 psi. Flanged up BOPE and tested with 1500 psi. Drilled out cement collar and guide ~hoe. Drilled 9-7/8" hole to 1836'. 9-27 1,836 9,731 Drilled 9-7/8" hole to 9731', mud 72-74 pcf. ~rbo ~2 2893-2994' faced West Turbo t~3 7204-7232' faced S85E ~8 9,731~ 9,747 Drilled 9-7/8" hole to 9747' mud 73 pcf ~rbo t~4 9731-9747' faced S70E Stuck bit at 2903' on trip out. Worked loose in 3 hours. Bit would not go do~ hole. Pulled up and stuck at 2887'. Spotted 30 bbls oil, worked pipe ~d jarred with Bowen surface jars, worked bit free. Attempted to re~ up out of hole, no success. Placed 9-7/8" stabilizer 31 stands above bit. Ran in with stabilizer and re~ed 2870-2963'. 29 9,747 Attempted to pull out and stuck bit at 1833'. Ran Dia-Log free-point ~dicator, pipe free to 1805', top of turbodrill. Ran in with bumper subs ~d bumped on fish with no success. Ran Dia-Log string shot and backed off drill pipe at 1708'. Ran in with jars, jars parted. Pulled out of hole. , ,, , , , 15" 400 1752 10-3/4" 1732' 9-7/8" 1752 9747 ~ , , ~~ 5", 19 5~ ~IZE~ ' ',, 'l ,, ,, , PD'4A (.Rev. 5-63) Prmtea in U.S.A. ( $~I~L~ OIL ~O~{PA~ . ( w..=,o ~ C_34~_~ 26 Middle Ground Shoal DRn. T. ING R PORT Sec. 26 Kenai April 13, 1968 ~ ~ ~ ~tV ~ ~- TSN, R13~ S.M. I~Y DEPTHS REMARKS DIVISION OF MINES & MINEP. AL~ iRON I TO ANCHORAGE 1968 March 30 9,747 Ran in with overshot, no success. Ran Dia-Log string shot and backed off drill pipe at 1738'. Ran in with Bumper sub and jars, no success. Ran string shot, backed off at 1772'. Ran collar locator, checked casing to shoe, ok. Ran in with bumper sub. Spotted 20 bbls oil and bumped on fish, no success Ran string shot and backed off at 1805' top of turbodrill. 31 9,747 RAN ELECTRICAL LOG~ RUN 1:1732 TO 1804'. Log indicated no other casing ~loSe to wellbore. Ran in with Washover pipe. Unable to get over top of. fish, pulled out. Ran in with bit and reamed above fish 1741-1802'. April _ 1 9,747 Ran in with washover pipe. Washed over pipe to 1830'. Ran collar loca- tot, fish fell free. Ran in with bit and reamed 1780-1870', ran bit to 9695'. Located top of f¢~h at 9695'. · 2 9,747 Conditioned mud. Ran in with overshot. Worked fish to 9719'. Pulled out, no recovery. Dressed fishing tools and ran in hole. 3 9,747 9,83~ Circulated and worked over fish. Recovered entire fish. Ran in and drilled 9-7/8" hole to 9834's mud 74 pcf. 4-11 9,834 11,23] Drilled 9-7/8" hole to 11,233' mud 72-74 pcf 12 11,233 11,282 Drilled 9-7/8" hole to 11,282'. Conditioned mud to log. RAN DUAL ,,, INDUCTION IATEROLOG, RUN 1,1730-1!a256' and BOREHOLE COMPENSATE? SONIC LOG RUN ~ 7000-11: 256'. 13 11,282 Conditioned hole for casing. CEMENTED 7" CASING AT 11,259' .WITH 1200 SACKS° Ran 7" Buttress casing, (23#, N-80, 35-4711'; 26~/, N-80, 4711- 8646'; 29~/, N-80, 8646-11,259') with shoe at 11,259' and float collar at 11,214'. Cemented with 200 cuft water ahead of 1200 sacks class "G" (118 pcf slurry) cement mixed with 1% CFR-2. Displaced cement with 2485 cuft inlet water. Bumped plug with 2500 psi. = , ,, , , , ,,,End , CONDITION AT'~I~Z~I:~D OF PERIOD , , , ,, · Ir'~ ImOM 'TO -- Iii I i iii [ I i i I 15" 400 1752 10-3/4" 1732' 9-7/8" 1752 11282 7" 11,259' · I~RILL PIP~ 5" srz_-- 19. 5~k ,~ , , , ,, ~ , , , , , , , ,,, , , , , PD'4A rRev. 5-63) Printed ,n U.S.A. w~.~. ~o C-34-26 Middle Ground Shoal DIULLING t EPOR ~nai April 16, 1968 T8N, R13W, S.M. 1 lgBSa' c. ,.. DAY DE?rHS DIVISION OF MINES & MINEP, AL,S REMARKS ANCHORAGE April 14 PBTD 11,213 ~ SPE~Y-S~ G~O-S~Y ~OM S~ACE TO 3000'. ~ G~ ~Y-COL~- . and displaced mud with diesel. 15 PB~ 11,213 Ran 3-1/2" E~ tubing to 9848' with packer at 9779'. Installed tree and flow line. Tested tubing with 1000 psi. 16 PBTD 11,213 Perforated with 4 - 1/2" jets per foot - 9919-9926'f 9932-9957', 10,247-10,256' 10,284-10,305' 10,355-10,365' 10 397-10,453' 10,526-10,540', 10,547-10,644' 10,690-10,752' 10 786-10 864' 10,884-10,902', 10,912-10,941', 10,962-10,994'. Ran pressure survey. Placed well on production. Released rig 4:00 p.m. 4-16-68. . .. .. . End.. . . ~ ~NDITION AT ~O~OF PERIOD HOLE ~NO 8~z~ DE~H G~ , ,, i,, , .,, , , , , I;l ~ROH ,, , 15" 400 1752 10-3/4" 1732' 9-7/8 ~752 1~282~ 7" 11,259' ,,~ , r , ' , , , , , , SIGNED t~ ~ C'4 Cq C,l .'4 "'~--,..~328. 29.00 SW 1. 411, 50.00 SW 5605. 29.75 SW 2, 5782. 2.8.75 SW 5. 5ghS. 28.25 SW 8. 61~6, 28,50 SW 629~, 29,75 St~ 7, 6340. 29,75 SW 8. 6511. ~0.00 SI~ 12, b614, ~U,Ou SW ~1, 6791, ~0,50 SW 9, 6917, ~0,75 SW 9, 7~2~. ~0.50 SW 7579, 50,00 SW 7, 776~, ~1.00 S~ 7, 7987. ~1.50 SW 7, 8067, ~1,25 SW 821~, ~1,50 SW O, 8268, ~2.25 SW O, 8~9~, 32,25 Sl~ 9, 86~9, ~1.50 SW 11, 2880, ~0,75 SI.I 11. 903~. 3U.25 SI~ 1~. 9202, ~0,75 5W 15, 9202, ~0,75 S~ 15, 2 .so sw sw zoo . Z0516, 2C,00 SW 10. 10647. 27,75 SW 10, 10769, 28.25 SW 12, ~0926, 31.75 SW 10. 11015, ;},00 S~ 1~. .Zl17~, 20.75 S~; 17, 1i282, 29.25 S~I 19, 12b. 83. 194. 177. 166. 188. 158. 46. 171. 123. 157. 126. 192. 95. 61. .SI. 128. 155. 184. 224. gO. 147. 54. 125. 256. 231. 153. 169. O. 122. 114. 171. 122. 38. 61. 194. 70. 150. 128 . 144. 131. 122. 157. ~9. 158. 109. 108.45 71,88 168.43 155.18 146.22 165.21 137.17 39.93 149.09 106.52 135.27 108.28 165.85 81.64 52.82 26.64 110.2~ 134.23 157.71 190.99 68.39 125.33 45.66 10~;.71 219.27 199.52 132.16 145.23 0.00 105.11 98,97 150,27 lo7,71 33.93 54.70 170.gg ~1.22 132.44 113.79 12 9.42 115.93 107.46 135.50 74.64 137.17 95.10 4742.70 4814.58 4983.01 5138.19 5284.42 5~49.63 5586.81 5626.75 5774.84 5881.36 6016.63 6124.92 6290.77 ~372.42 6425.25 6451.89 6562.18 6696..41 6854.13 7045.12 7113.51 7238.85 7284.52 7390.24 7608.51 7807.04 7939,20 8084.44 8084.44 8189.56 8288.54 ~438.~1 8546.53 C580.47 0,00 2185,63 :~00 28 0,00 2227,07 ~' .... '~.,.98~11 0,00 ' "~2323,28~ '~ ......... 194,75 0,00 0,00 0,00 0.00 0,00 0,00 0.00 0.00 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0o00 0,00 0,00 0,00 0,00 2408.09 2485.90 2575.58 2653.20 · -~ 2759.44 2819.81 2898.51 2962.14 3056.75 3103.44 3133.57 3149.30 3214.10 3291.03 3385.09 3501.25 35~2.35 3618.21 3646.67 3712.55 3843.86 3959.20 4034.58 4118.05 4!19.05 4178.83 4233.47 4311.50 4365.32 4381.84 ~ 187.33 176.39 170.14 160.58 157.40 ......... ? 13 9.63 127.89 115.~3 105.35 ~5.24 71.85 67.08 65.15 60.62 51.17 39.62 ~" 25.36 19.58 7,57 3.06 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 · ' 0.00 0.00 ~' 0.00 0,00 0,00 0,00 '~ 0.00 0,00 ...... i..~L.,,, ..... 0. O0 8635.17 ....... 0.00 8806.07 8867.29 8999.73 9113 ,'53.J 9242.95 9358.89 9466.3b 9599.86 9674.50 9~11.6~ 9906.78 0.00 0.00 ..~, 0.00 0.00 0.00 0.00 0.00 0.00 ~ 0.00 ,~ 0.00 ~. 0.00 ....~' ...~.~ ..~.;. 4408.23 41,99.16 4532.85 4602.74 4660.91 4723.08 4783.15 4839.63 4920.99 4968.03 5043. O0 5093.36 0,00 0,00 0,00 0.00 0,00 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0,00 0.00 0.00 0.00 0,00 0.00 0.00 0,00 0,00 0.00 7,37 32.89 55.42 74.07 96.43 96,43 108.25 122.89 146.75 166.34 170.75 176.37 189.15 193.29 201.87 209.01 219.97 230.57 242.57 256.92 2~8.6b 291.57 308.91 1.53 2172.15 1.69 2213.65 0.29 2309.90 1.00 ~39~,. 99 0.91 2473.26 1.02 . 2562.95 1.22 2041.16 1.17 2748.35 0.41 2909.25 0.72 2888.50 0.20 2952.57 O. 83 3048.10 2.20 3095.43 5.93 3125.76 4.06 3141.57 1.21 3206.53 1.03 '3283.84 0.54 3379.37 U. 22 3495.13 0.72 3536.47 0.39 3612.86' 1.39 3641.52 0.00 3707.C5 0.51 3840.31 0.32 3957.27 1.05 4032.93 0.42 4117.45 O.O0 4117.45 1.68 4178.77 1.88 4234.10 0.93 4313.27 1.23 43&~.04 6.88 4354.77 2.34 4411.42 1.40 4502.90 1.27 ~536.75 O. 67 4607. O0 0.59 4C65.4C 1.27 4728,12 1.34 ~7~8.66 O. 87 4845.69 2.32 '4927.69 2.79 4975.28 2.28 5051.35 1.01 5102.55 Form No P--4 REV STATE OF ALASKA O~L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL SUBMIT IN DEPLICATE 2 N~E OF OPgRATOR Shell Oil Company 3 ADDRESS OF OP]~RATOR OTHER 430 Seventh Avenue, Anchorage, Alaska 99501 4 LOCATION OF WELL Conductor 3, Leg 1 @ 3.17'N & 4o89'E from center Leg 1 @ 541.65'N & 1596.41'W from SE corner, Sec 23, T8N, R13W, 5 APl NL~E~CA.L CODE 50-133-20093 6 LF~tSE DESiGNAilON A\-D SERIAL ~O ADL 18756 IF INDI ~N %LOT-lEE OR TRIBE NAME None 8 L~.'IT,FA_tLM OR LEASE N A_ME Middle Ground Shoal 9 WELL NO C-34-26 10 FIELD AND POOL OR WILDCAT Midd]e Ground Shoal 11 SEC, T R 1%{ ( BO/'TOM HOLE OBJECTIVE ~ Sec. 26, T8N, R13W, S.M. 12 PERMIT NO 68-19 13 REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET A/ND VOLUMES USED, PERFORATIONS, TF, STS A.ND RESULTS, FISHING JOBS, JUNK IN HOLE AND SIDE-T-R~CKED HOLE AND ANY OTHER SIGNIFICANT CTIANGES IN HOI~ CONDITIONS Recovered fish. Drilled 9-7/8" hole to 11,282'. Ran Logs. Cemented 7" casing at 11,259' with 1200 sacks. Ran log. Ran tubing to 9848' with packer at 9779'. Perforated with 4-1/2" jets per foot - 9919-9926' 9932-9957' 10,247-10,256' 10,284- 10,305', 10,355-10,365', 10,397-10,453', 10,526-10,540', 10,547-10,644', 10,690-10,752', 10,786-10,864' 10,884-10 902' 10 912-10 941' 10 962-10 994' Placed well on production. Released rig 4:00 p.m. 4-16-68. RECEIVED MAY 2 196B DIVISION OF MINES & MJNERA~ 14 I hereby and correct SIGNED . u~ru; Div. Exploitation Engine~A.~ ~RY - 1 ~8 NOTE--Report on this form ms req for each calendar month, regardless of the status of operaUons, and must ~ filed m duphcate w~th the Diws~on of Mines & Minerals by the 15th of the succeeding month, unless othe~lse directed SHELL OIL 430 '7'rH ANCHORAGE COMPANY AVEN U P" ALASKA ggso ~ Form No P--4 REV 9-~0-$T STATE OF ALASKA OiL AND GAS CONSERVATION COMMITTEE SUBMIT L'q DEPLIC~TE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I OIL C GAS ~ WELL WELL OTHER NAME OF OPEI:OkTOR Shell Oil Company ADDRESS OF OPERATOR 430 Seventh Avenue~ Anchorage, Alaska 99501 LOCATION OF WELL Conductor 3, Leg 1 @ 3.17'N & 4o89'E from center Leg 1 @ 541.65'N & 1596.41'W from SE corner, Sec. 23, TSN, R13W~ 5 AP1 NL'AIEKICA.L CODE 50-133- 20093 6 LEASE DESIGNATION AND S~%RIAL NO ADL 187 56 iT IF I.'%-DI~N %LOI IE~. OR TRIBE .N'A.%IE None 8 L~.'IT,F.~RAI OR LEASE NA-ME Middle Ground Shoal 9 l,v~lJ.. N'O C-34-26 10 FID A-%'D Poom OR WILDCAT Middle Ground Shoal i1 SEC, T, R, M (BO/'rO.%{ HOL~E O~IVE~ Sec. 26~ TSN, R13W, S.M. 12 Pi,-~RfvlIT biO 68-19 '13 REPORT TOTAL DEPTH AT END OF MONTH, CHANOES Ibi HOLE SIZE CASING AIN-D CE/ViENTING JOBS INCLL'DING DEPTH SET AN~ VOLLrMES USED, PE~RFORATIONS, TESTS ~ RESULTS FISHING JOBS, JUNK IN HOLE AND SIDE-Tt~CKED HOLE AND A_NY OTIfER SIGNIFICANT CI-IAN~ES IN HOI~ CONI)ITIONS Spudded 11:00 A.M. 3-5-68 Drilled 15" hole to 1752'. Cemented 10-3/4" casing at 1732' with 1500 sacks. Drilled 9-7/8" hole to 9747'. Fishing, turbo drill stuck at 1804' on trip out. R[C£1VI O APR 5 19 B DIVISION OF MINES & MINERALS ANCHORAGE S~G~ -- -- . r % TITI~ Division Exploitation En~ NOTE--Report on th~s form ts reqmred for each calendar month, regardless of the status of operaUons, ancl must be hied m duphcate w~th the D~ws,on of Mines & Minerals by the 15th of the succeeding month, unless otherwise d~rected · ~brmry 26, ~968 l~hi~ ~rmmd Shoal C-3~-26 Shell Ot~ Company, operator Divi~on F, xp~tcaCiou Eug~er ~30 Sevsn~h Avenue Anchorase, Alaska 9~501 Daar S~r: Euclosed please find the approved appllLcation for perutc to drill c~e ref~erenced veil. ~ samploa ~nd core chips are not required. Very truly yours Thomas a. 14arslmll, Jr. PeL-roleum Supervisor FORM SA- I B 125 5M 8/67 MEMORANDUM TO: r- FROM: State of Alaska DATE : SUBJECT: · < FORM SA- I B 125 5M 8/67 MEMORANDUM State of Alaska TO: J'- DATE : FROM: SUBJECT,' SHELL OIL 430 7th ANCHORAGE. COMPANY AVENUE ALASKA 99501 February 20, 1968 Private & Confidential STATE OF ALASKA 3001 Porcupine Drive Anchorage, Alaska Attention ToR. Marshall, Jr° Gent lemen: Enclosed for your approval is our Application for Permit to Drill well S.A.S.M.G.S° C-34-26 from our Platform "C"o Also enclosed is our check in the amount of $50.00 for the filing fee. Very truly yours, RoD. Allen Division Exploitation Engineer Enclosures: Filing Fee Check (1) Application to Drill (3) Location Plat (3) Blowout Prevention Program (3) For~ REV t SUBMIT IN TRII~ {TE (Other m~truct~ons on reverse rode) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 1R TYPg OF WORK DRILL b. TYP~- OF WI~LL WgLL WmLL OTHER ZONg ZONE 2 NA~ OF OP~TOR Shell 0~1 ~mpany 3 ~D~ ~ OPhiR 430 Seventh Avenue~ ~cho~gge~ Alaska 99501 DEEPEN [-I PLUG BACK E] 4 LOCATION OF WELL At s"rface Conductor 3, Leg 1 @ 3o17'N & 4.89'E from center leg 1 at 541.65'N and 1596.41'W from SE corner, Sec. 23, T8N, R13Ws At proposed prod zone S ° M. *See Below 13 DISTANCE IN MILES AND DIRECTION F.%OM NEAREST TOWN OR POST OFFICE* 17 miles NW of Kenai} Alaska 14 BOND INFOI~VlATION State Wide 0il & Gas TYPE Surety and/or No TIC 136503 i16 NO. OF ACRES IN LEASE 5120 19 PROPOSED DEPTI-I 11,360' (MLLW~ 15 DISTANCE FROM PROPOSED* LOCATION TO NEAR~ST PROPERTY OR LEASE LINE, FT 500 ' (Also to nearest drtg, un~t, zf any) '{} DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL D~ILLING, COMP~ETE~, OR APPLIED FOR, FT 1250 21 ELEVATIONS (Show whether DF, RT, CR, etc ) 105' D.F. 23. PROPOSED CASI~I~ A/~i~ CEMENTING PROGRAM API 50-133-20093 6 LEASE DESIGNATION AND S~L NO. 18756 - ADL IF INDIA2~, Al.,LO'x-r~:.: OR ~ NAM~ None UNIT~ FAB~ OR LEASE NAME Middle Ground Shoal 9 WELL NO C-34-26 10 FID AND POOL, OR WILDCAT Middle Ground Shoal 11 SEC , T , R , M , (BOTTOM HOLE OBJECTIVE) Sec. 26, T8N, R13W, S.M. _ a.~o,,,? $100,000,00 17 NO ACRES ASSIGNED TO THiS WELL 80 20 ROTARY OR CABLE TOOLS Rotary 22 APPROX. DATE WORK WILL START* 2-26-68 SIZE OF HOLE F SIZE OF CASING ~EIGHT PER FOOT GRAD~ SETTING DEP'I~I QUANTIT~ OF CEM~N~ 15" 10-~/4" 40.5# J 1700'_+ 1500 sx ~£,~}I+ ~'~' 9-7/8" 7" 23, 26} 29¢P N , 11,360'-+ 1200 sx q~ ~ ~ , , , . , , *Top of productive zone - 9650'+ (8500'+ TVD) 1400'+ N & 1500'+ W from SE corner~ Sec. 26, T8N, R13W, S.Mo Bottom Hole Location- 11}360' (9980' TVD)500'N & 1880'W from SE corner, Seco ~26~ ~8N, R C ~ ABO~ SPA~ D~BE ~OPOS~ P~R~ If ~I ~ ~ dee~n or pl~ ~, give ~ p esen~ pro~s~ ~w produ~zve ~. If pro,~ m ~o ~fll or d~n ~eo~.o~ly, ~ve pe~men~ ~ on ~bs~a~ ~t~ ~ ~ea~ ~d ~ue ve~l dep~ G~ve blo~ut preventer p~r~ (This space for State off~ce use) ISA1ViPLES AND COKE CHIPS I~F~UIRED [] YES ~'~o DIRECTIONAL SURVEY RE~U/RED YES [] NO CONDrrlONS OF APPROVAL, IF ANY tOTHER A P I. ~CAL CODE API 50-133-20093 Executiv~ ~ecretar? *See Instructions U~;a~l~E~:m%i~mrnittee --I T. 8 N., R.13 W., S. M. 23 26 · C-23-26 26 35 SAS ADL 18756 PaPSS ADL 18746 ~ C-24-26 LOCATION OF CONDUCTOR 3 , LEG # PUBLIC CONDUCTOR 3, LEG No ! LOCATED 3.17'N AND 4.89'E FROM CENTER OF LEG No 1 CENTER LEG No I LOCATED 541.65' NORTH OF THE '~'~UTN LINE AND 1596.,~1' WEST OF THE EAST LINE. C-3 4-23 · ~ LEG I 3 4 /I[ 23 24 26 25 · C- 31-26 C.34-26 o 1880~ W 2E 25 35 36 LAND BOTTOM HOLE LOCATION WELL C-34-26 DESCRIPTION 500'N AND 1880'W FROM THE SE COR. OF SEC. 26, TSN, R13W, S.M. AWN BY: N.L.B. CHECKED BY: J.D.M. 20 FEBRUARY 1968 SHELL OIL COMPANY LOCATION OF SHELL-ATLANTIC-STANDARD WELL C.34.26 SCALE' I"- 1 000' Z 21- 6829 T. 8N., R.13W., S.M. - COOK I I III II I. I I I I II II II IBII IN SEC. 26 INLET - STATE OF ALASKA III III II I I II I I IIII I IIIII I I --1 .DRILLING~ CASING AND BLOWOUT PREVENTION PROGRAM WELL C-34-26 MIDDLE GROUND SHOAL- PLATFORM "C" COOK INLET ~ ALASKA 1. Move rig over 24" conductor 3, Leg 1. Install 20", 2000 psi Hydril pre- venter and riser. Drill 15" hole to 1700'+. Run 1700'+ of 10-3/4" 40.5# J-55 Buttress casing. Cement with 1500 sacks API cement, (1300 sacks gel cement and 200 sacks neat cement). · 3. Imnd casing and flange up ~3-5/8" 3000 psi preventer stack consisting of Double Shaffer Gate and G.K. Hydril. 4. Drill 9-7/8" hole to 11,360'±. Run logs at TD. Run 11,360'± of 7" 23#, 26#, and 29# N-80 Buttress casing. Cement with 1200 sacks API cement° 5. Run 4-1/2" 12.6# N-80 Buttress tubing string equipped with packers. 6. Perforate productive zone with 4 shots per foot at selected intervals. Place well on production.
