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Home My WebLink About195-1191. 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 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 12,047 feet 10,226 &±10,236 feet true vertical 10,045 feet N/A feet Effective Depth measured 8,490 feet 7,827 feet true vertical 7,707 feet 7,206 feet Perforation depth Measured depth 7,905 - 10,015 feet True Vertical depth 7,275 - 8,682 feet Tubing (size, grade, measured and true vertical depth)2-7/8" & 2-3/8" 6.5 L-80 / 4.7 L-80 7,903 MD 7,273 TVD 7,827 (MD) 341 (MD) Packers and SSSV (type, measured and true vertical depth)MFH 15-18# Hyd Pkr 7,206 (TVD) Halliburton TRSV SSV 341 (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 5" 3-1/2" 10,743 MD 330 1,990 12,045 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 6 Representative Daily Average Production or Injection Data 10038 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-119 50-733-20179-03-00 Plugs ADL0018754 MGS A41A-11RD2 Other: Safe Acid 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-087 95 Authorized Signature with date: Authorized Name: 64 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 5 Gas-Mcf 479 Pumped 3 totes of Safe Acid followed by 48 bbls of FIW. Final Pressure: TBG/IA/OA = 0/0/35 Oil-Bbl 1 Water-Bbl Intermediate 7,905 - 10,015 Junk 5. Permit to Drill Number: 2 Middle Ground Shoal / MGS Oil PoolN/A measured 7,765 5,089 Size 483 Liner Casing Structural Liner 1,365 Length 330 1,990 Conductor Surface slotted 13,450psi 24" 13-3/8" 7" 7,765 7,240psi 907 777-8376 13,940psi 330 1,934 7,148 9,192 10,041 Collapse Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 1,540psi 5,410psi 3,090psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: slotted Daniel E. Marlowe Operations Manager Burst PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:07 am, Oct 23, 2020 Digitally signed by Daniel Marlowe DN: cn=Daniel Marlowe, ou=Users Reason: I am approving this document Date: 2020.10.22 16:57:21 -08'00' Daniel Marlowe DSR-10/26/2020 RBDMS HEW 11/10/2020 _____________________________________________________________________________________ Updated By: JLL 10/22/20 SCHEMATIC Middle Ground Shoal Well: MGS A41A-11RD2 Last Completed: 11/13/2018 PTD: 195-119 API: 50-733-20179-03 PBTD = 12,045’ TD =12,047’ 24” KB: 38’, KB to MSL: 116’, MSL to Mudline: 73’ 3-1/2” 4 5 6 7 8 9 10 7” 5” 3 2 02/19/2006 Fill @ 11,988’ 13-3/8” 1 X 10/18/20 Scale @ 8,490’ CASING DETAIL Size Wt Grade Conn ID Top Btm Cement 24” Driven Conductor Welded Surf 330’ N/A 13-3/8” 61 K-55 STC 12.515” Surf 178’810 sx & 170 sx (top job) K-55 BTC 12.515” 178’ 1,038’ 54.5 K-55 BTC 12.615” 1,038’ 1,080’ 68 K-55 BTC 12.415” 1,080’ 1,990’ 7” 26 N-80 BTC 6.276” Surf 801’ 824 sx S-95 LTC 6.276” 801’ 1,547’ 29 N-80 LTC 6.184” 1,547’ 5,224’ S-95 LTC 6.184” 5,224’ 5,686’ L-80 LTC 6.184” 5,686’ 7,765’ 5” 18 P-110 STL 4.276” 5,654’ 10,743’ 560 sx 3-1/2” (slotted)9.3 J-55 BTC 2.992” 10,680’ 12,045’ N/A TUBING DETAIL 2-7/8” 6.5 L-80 8rd EUE 2.441” Surf 5,639’ 2-3/8” 4.7 L-80 8rd EUE 1.995” 5,639’ 7,903’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 38’ 38’ Hanger CIW-DCB-FBB, 11’x3 ½” EUE lift & susp w/3” Type “H” BPV profile 1 341’ 341’ 2.313 4.650 SCSSV –Halliburton TRSV NE 2 1,889’ 1,842’ 2.441 4.750 GLM #1 –2-7/8” Weatherford SFO-1 3,509 3,321’ 2.441 4.750 GLM #2 –2-7/8” Weatherford SFO-1 4,800’ 4,462’ 2.441 4.750 GLM #3 –2-7/8” Weatherford SFO-1 3 5,639’ 5,195’ 1.995 3.668 X-Over to 2-3/8” 4 5,774’ 5,316’ 1.995 3.500 GLM #4 –2-3/8” BST Lift Systems, GLMAT-1HP Slim hole, T-1 Latch 6,449’ 5,926’ 1.995 3.500 GLM #5 –2-3/8” BST Lift Systems, GLMAT-1HP Slim hole, T-1 Latch 7,085’ 6,510’ 1.995 3.500 GLM #6 –2-3/8” BST Lift Systems, GLMAT-1HP Slim hole, T-1 Latch 7,731’ 7,116’ 1.995 3.500 GLM #7 (Orifice)–2-3/8” BST Lift Systems, GLMAT-1HP Slim hole, T-1 Latch 5 7,778’ 7,160’ 1.995 3.500 Chemical Injection Mandrel –GLMATCI-1HP 6 7,827’ 7,206’ 1.929 4.070 Packer - MFH 15-18# Hydraulic Retrievable w/ 30k lb shear release 7 7,872’ 7,246’ 1.875 3.063 X Nipple 8 7,903’ 7,273’ 1.995 3.063 WLEG 9 10,226’ 8,815’ CIBP 10 ±10,236’ ±8,821’ CIBP (partially set CIBP) PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status A-1 6,084' 6,136' 5,595' 5,642' 52' Isolated B 6,574' 6,638' 6,040' 6,098' 64' Isolated B 6,659' 6,677' 6,117' 6,134' 18' Isolated B 6,746' 6,772' 6,197' 6,221' 26' Isolated C 6,845' 6,857' 6,288' 6,299' 12' Isolated C 6,870' 6,881' 6,311' 6,321' 11' Isolated C 7,157' 7,230' 6,577' 6,645' 73' Isolated C 7,251' 7,289' 6,665' 6,701' 38' Isolated F1 7,905’ 7,928’ 7,275’ 7,295’ 23’ 08/07/19 Open F1 7,934’ 7,965’ 7,300’ 7,327’ 31’ 08/07/19 Open HK2 8,715' 8,733' 7,858' 7,870' 18' 11/09/18 Open HK2 8,750' 8,795' 7,882' 7,912' 45' 11/09/18 Open HK2 8,820' 9,018' 7,928' 8,061' 198' 11/09/18 Open HK2 9,038' 9,312' 8,074' 8,251' 274' 11/09/18 Open HK3 9,367' 9,480' 8,285' 8,354' 113' 11/09/18 Open HK3 9,497' 9,790' 8,364' 8,545' 293' 11/09/18 Open HK3 9,824' 10,015' 8,566' 8,682' 191' 11/09/18 Open HK-3 West (Repeat) 10,530' 10,666' 9,029' 9,134' 136' 11/03/18 Isolated Slotted Liner: HK-3 to HK-1 West (Repeat) 10,743’ 12,045’ 9,192’ 10,041’ 1,302' 11/03/18 Isolated Well Name Rig API Number Well Permit Number Start Date End Date MGS A41A-11RD2 SL / WL 50-733-20179-03 195-119 9/24/2020 10/18/2020 Daily Operations: 10/01/2020 - Thursday Bring well online post 5 day oilsafe AR acid soak 10/18/2020 - Sunday RU WL unit and PT. Drift w/ 1.75" bailer. Deepest tag 8490' MD. Scale in bailer. Not deep enough for perforation interval (8579' top of interval). RD. 09/25/2020 - Friday Finished filling IA w/FIW (180.56 bbl). Rigged up acid pump. Pressure tested equipment to 3700 psi. Pressure test pass /all good. Pumped 3 totes of Safe Acid. Pumped 48 bbls of FIW to spot acid. Rig down and let acid soak. Hilcorp Alaska, LLC Well Operations Summary 09/24/2020 - Thursday Shut in well and start filling well IA w/FIW. 1 Winston, Hugh E (CED) From:Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Sent:Wednesday, March 25, 2020 9:21 AM To:Joe Kaiser Cc:Juanita Lovett; Dan Marlowe Subject:[EXTERNAL] RE: Change of Procedure Request: MGS A41A-11RD2 PTD 195-119 Sundry#: 320-087 Joe, You have approval to modify the sundry 320‐087 with an acid soak as proposed below. It may be repeated as needed in order to gain access to the perforation interval. Update MOC as required. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907‐301‐4533 cell 907‐793‐1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Joe Kaiser <jkaiser@hilcorp.com> Sent: Tuesday, March 24, 2020 3:36 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: Change of Procedure Request: MGS A41A‐11RD2 PTD 195‐119 Sundry#: 320‐087 Mr. Schwartz: This message is in regards to MGS A41A‐11RD2 PTD 195‐119 Sundry#: 320‐087. We are seeking approval for additional procedures prior to executing work in the sundry. Recently, slick line was on the well prior to rigging up E‐line for the perforations outlined in the sundry. We tagged high at ~8,475’. This is ~105’ from the top perf. We had this fill analyzed and confirmed scale. Hilcorp requests approval to perform a safe acid soak on this well. Our intention is to target the scale in the tubing. Not necessarily the formation. We may have to repeat the procedure below several times to provide sufficient diameter to allow perf guns to pass. The procedure will be: 1) SI Well and fill backside. 2) Pressure test surface lines and pumping equipment to 3,700 psig. 3) Pump 3 totes of Safe Acid (~19.6 bbl) 4) Pump 48 bbl FIW. 2 5) SI well for 5 days. 6) Bring online 7) RU Slickline, bailing, and run dummy guns 8) Continue with E‐line per Sundry 320‐087. With AOGCC approval, this will be captured on Hilcorp’s Procedure Change Form. If you have any questions or comments, please let me know. Thank you, Joe Kaiser (working remotely) Hilcorp Alaska, LLC CIO Operations Engineer 907‐952‐8897 The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. 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. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Daniel Marlowe Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .00gcc.alaska.gov Re: Middle Ground Shoal Field, Middle Ground Shoal Oil Pool, MGS A41A-11RD2 Permit to Drill Number: 195-119 Sundry Number: 320-087 Dear Mr. Marlowe: 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, M. rice Chair DATED this day of March, 2020. ,1BDMS1�9Aft o 4 BN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS RECEIVED FEB 2 4 2020 0-rs 3/2/2 c-) 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate LJ Repair Well LJ a wcwraumra+nnmruwn', Rews 17 VVVV Suspend❑ Perforate 0 Other Stimulate ❑ Pull Tubing E]Change Approved Program El 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: Hiloorp Alaska, LLC Exploratory ❑ Development ❑✓ 195-119 ' Number 3. Address: 3800 Centerpoint Drive, Suite 1400 Stmtigraphic ❑ Service ❑ 6. API Number: 50-733-20179-03-00 ' Anchorage, AK 99503 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 44A Will planned perforations require a spacing exception? Yes ❑ No ❑✓ MGS A41A-11 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): Middle Ground Shoal / Middle Ground Shoal Oil Pool ADL0018754 ' 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): 12,047 10,045 10,226 8,815 2,730 psi 10,226 &±10,236 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 330' 24" 330' 330' Surface 1,990' 13-3/8" 1,990' 1,934' 3,090 psi 1,540 psi Intermediate 7,765' 7" 7,765' 71148' 7,240 psi 51410 psi Liner 15,089' 5" 10,743' 9,192' 13,940 psi 13,450 psi Liner 1 1,365' 3-1/2" 12,045' 10,041' 1 slotted slotted Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,905 -10,015 7,275 - 8,682 2-7/8" & 2-3/8" 6.51 L-80 & 4.7 / L-80 7,903 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): MFH 15-18# Hyd Pkr & Halliburton TRSV SCSSV 7,827 (MD) 7,206 (TVD) & 341 (MD) 341 (TVD) 12. Attachments: Proposal Summary Q Wellbore schematic ✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/9/2020 OIL Q - WINJ ElWDSPL ❑ 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: Daniel E. Marlowe Contact Name: Joe Kaiser Authorized Title: Operations Mag2glar Contact Email:kaiser hiloor .Com 94 9 Contact Phone: (907) 777-8393 Authorized Signature Date: Z G COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: G —DO Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: iBDMS -T-'^MAR 0 4 2020 Post Initial Injection MIT Req'd? Yes ❑ No ❑ 4 ,.,Lul 1 V 1 Spacing Exception Required? Yes1No Subsequent Form Required: 1 II aD THEAPPROVEDWl Approved by: �7Yf _ COMMISSIONER THE COMMISSION Date: Submit Form and Fo Approved a plicatio i o he date of approval. Attachments in Duplicate U Hilcurp Alueku, LLC Well Prognosis Well A41A-11 RD2 Well Name: MGS A41A-11rd2 API Number: 50-733-20179-03 Current Status: Gas -Lifted producer Leg: Leg #2 Estimated Start Date: 3/9/2020 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 195-119 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907) 952-8897 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: 3,511 psi @ 7,802' TVD 0.45 psi/ft (injector gradient to surface) Maximum Expected BHP (Hemlock): 3,511 psi @ 7,802' TVD 0.45 psi/ft (injector gradient to surface) Maximum Potential Surface Pressure: 2,730 psi 0.1 psi/ft (gradient per 20 AAC 25.280(b)(4)) Brief Well Summary The A41A-11RD2 was originally a West flank water injector that was converted to an East flank production in October 2018. This workover will perforate Hemlock sands HK1C, not originally targeted in the re -completion. 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 IM KB: 38', KB to MSL: 116', MSL to Mud line: 73' I I I I I I I � I I I I 102/19/2005 rill C^1 1 111,988' 1 PBTD =12,045' TO =12,047' SCHEMATIC Middle Ground Shoal Well: MGS A41A-11RD2 Last Completed: 11/13/2018 PTD: 195-119 API: 50-733-20179-03 CASING DETAIL Size Wt Grade Conn ID Tap Btm Cement 24" Driven Conductor Welded Hanger CIW-DCB-FBB, 11'x3 Y," EUE lift & susp w/3" Type "H" BPV profile Surf 330' N/A 2.313 4.650 K-55 STC 12.515" Surf 178' 810 sx III 170 sx (top 61 K-55 BTC 12.515" 178' 1,038' 13-3/8" 54.5 K-55 BTC 12.615" 1,038' 1,080' job) 4,462' 68 K-55 BTC 12.415" 11080' 1,990' 1.995 3.668 X -Over to 2-3/8" N-80 BTC 6.276" Surf 801' GLM #4-2-3/8" BST Lift Systems, GLMAT-SHP Slim hole, T-1 Latch 26 S-95 LTC 6.276" 801' 1,547' 7" 5,926' N-80 LTC 6.184" 1,547' 5,224' 824 sx 29 S-95 LTC 6.184" 5,224' 5,686' L-80 LTC 6.184" 5,686' 7,765' 5" 18 P-110 STL 4.276" 5,654' 10,743' 560 sx 3-1/2" (slotted) 9.3 J-55 BTC 2.992" 10,680' 12,045' N/A 2-7/8" 1 i0 Srd I I i 1 2.441" 1 Surf 5,639' 2-3/8" 1 4.7 1 L-80 I End EUE 1 1.995" 1 5,639' 7,903' JEWELRY DETAIL No th (MD) Depth (TVD) ID OD Item 38' 38' Btm (MD) Top (TVD) Hanger CIW-DCB-FBB, 11'x3 Y," EUE lift & susp w/3" Type "H" BPV profile 1341' Date 341' 2.313 4.650 SCSSV- Halliburton TRSV NE 5,595' 1,889' 1,842' 2.441 4.750 GLM#1-2-7/8"Weatherford SFO -1 2 1,509 3,321' 2.441 4.750 GLM#2-2-7/8"Weatherford SFO -1 Isolated 4,800' 4,462' 2.441 4.750 GLM #3-2-7/8"Weatherford SFO -1 3 5,639' 5,195' 1.995 3.668 X -Over to 2-3/8" 6,197' 5,774' 5,316' 1.995 3.500 GLM #4-2-3/8" BST Lift Systems, GLMAT-SHP Slim hole, T-1 Latch 6,845' 6,449' 5,926' 1.995 3.500 GLM #5-2-3/8"EST Lift Systems,GLMAT-1HP Slim hole, T-1 Latch 4 7,085' 6,510' 1.995 3.500 GLM #6-2-3/8'EST Lift Systems,GLMAT-1HP Slim hole, T-1 Latch 11' 7,731' 7,116' 1.995 3.500 GLM #7 (Orifice( -2-3/8" BST Lift Systems, GLMAT-1HP Slim hole, T-1 Latch 6,577' 6,645' 7,160' 1.995 3.500 Chemical Injection.Mandrel-GLMATCI-1HP 7,251' 7,827' 7,206' 1.929 4.070 Packer -MFH 15-I8# Hydraulic Retrievable W/ 30k lb shear release Isolated 7,872' 7,246' 1.875 3.063 X Nipple P707,778' 7,903' 7,273' 1.995 3.063 WLEG 7,300' 10,226' 8,815' 08/07/19 Open CIBP 8,715' ±10,236' ±8,821' 7,870' 18' CIBP(partiall set CIBP) Updated By: JLL08/27/19 J PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status A-1 6,084' 6,136' 5,595' 5,642' 52' Isolated B 6,574' 6,638' 6,040' 6,098' 64' Isolated B 6,659' 6,677' 6,117' 6,134' 18' Isolated B 6,746' 6,772' 6,197' 6,221' 26' Isolated C 6,845' 6,857' 6,288' 6,299' 12' Isolated C 6,870' 6,881' 6,311' 6,321' 11' Isolated C 7,157' 7,230' 6,577' 6,645' 73' Isolated C 7,251' 7,289' 6,665' 6,701' 38' Isolated F1 7,905' 7,928' 7,275' 7,295' 23' 08/07/19 Open FS 7,934' 7,965' 7,300' 7,327' 31' 08/07/19 Open HK2 8,715' 8,733 7,858' 7,870' 18' 11/09/18 Open HK2 8,750' 8,795' 7,882' 7,912' 45' 11/09/18 Open HK2 8,820' 9,018' 7,928' 8,061' 198' 11/09/18 Open HK2 9,038' 9,312' 8,074' 8,251' 274' 11/09/18 Open HQ 9,367' 9,480' 81285' 8,354' 113' 11/09/18 Open HK3 9,497' 9,790' 8,364' 8,545' 293' 11/09/18 Open HK3 9,824' 111,015' 8,566' 8,682' 191' 11/09/18 Open HK -3 West (Repeat) 10,530' 10,666' 1 9,029' 1 9,134' 1 136' 11/03/18 Isolated Slotted Liner: HK -3 to HK -1 West(Repeat) 10,743' 12,045' 9,192 10,041 1,302 11/03/18 Isolated Updated By: JLL08/27/19 J nf KB: 38'. KB to MSL: 116', MSL to Mud line: 73' I i 5" I I I I I I I I I 102/1912006 Fill @ 1 111,988' 1 Fµ ' 31/2" PBTD =12,045' TD =12,047' PROPOSED Middle Ground Shoal Well: MISS A41A-11RD2 Last Completed: 11/13/2018 PTD: 195-119 API: 50-733-20179-03 CASING DETAIL Size Wt Grade Conn ID Tap Btm Cement 24" Driven Conductor Welded SCSSV- Halliburton TRSV NE Surf 330' N/A 2.441 4.750 K-55 STC 12.515" Surf 178' 810 sx& 170 sx (top 61 K-55 BTC 12.515" 178' 1,036' 13-3/8" 54.5 K-55 BTC 12.615" 1,038' 1,080' job) 5,195' 5,316' 68 K-55 BTC 12.415" 1,080' 1,990' 1.995 6,746' M#5-2-3/8"EST Lift Syste ms, GLMAT-1HP Slim hole, T-1 Latch N-80 BTC 6.276" Surf 801' #6-2-31W BST Lift SystemsGLMAT-1HP Slim hole, T-1 Latch M#7(Orifice)-2-3/8"BST Lift Systems,GLMAT-1HP Slim hole, T-1 Latch 26 5-95 LTC 6.276" 801' 1,547' 7" 7,160' WED LTC 6.184" 1,547' 5,224' 824 sx 29 S-95 LTC 6.184" 5,224' 5,686' L-80 LTC 6.184" 5,686' 7,765' 5" 18 P-110 STL 4.276" 5,654' 10,743' 560 sx 3-1/2" (slotted) 9.3 1-55 BTC 2.992" 10,680' 12,045' N/A JEWELRY DETAIL No Depih MDI 38' Depth (TVD) 38' ID OD Item Hanger CIW-DCB-FBB, 11'x314" FILE lift & susp w/3" Type "H" BPV profile 1 341' 341' 2.313 4.650 SCSSV- Halliburton TRSV NE FT Datefflsoolaed 1,842' 2.441 4.750 GUY #1-2-7/8" Weatherford SFO -1 5,595' 5,642' 3,321' 2.441 4.750 GLM#2-2-7/8" Weatherford SFO -1 6,574' 6,638' 4,462' 2.441 4.750 GUM #3-2-7/8" Weatherford SFO -1 d S 5,195' 5,316' 1.995 1.995 3.668 3.500 X -Over to 2-3/8" GLM#4-2-3/8"EST Lift Systems, GLMAT-1NP Slim hole, T-1 Latch 18' 5,926' 1.995 6,746' M#5-2-3/8"EST Lift Syste ms, GLMAT-1HP Slim hole, T-1 Latch 6,197' 6,221' 6,510' 7,116' 1.995 1.995 d #6-2-31W BST Lift SystemsGLMAT-1HP Slim hole, T-1 Latch M#7(Orifice)-2-3/8"BST Lift Systems,GLMAT-1HP Slim hole, T-1 Latch 6,845' 6,857' 7,160' 1.995 12' emical Injection Mandrel -GLMATCI-1HP 6 7,827' 7,206' 1.929 irCIRP1 ker- MFH 15-18" Hydraulic Retrievable w/ 30k Ib shear release 7 7,872' 7,246' 1.875 ipple 8 7,903' 7,273' 1.995 EG 9 10,226' 8,815' P 10 ±10,236' 18,821' 7,928' 71275' P (partially set CIRP) Updated By: JLL02/20/20 PERFORATION DETAIL Top (MD) Blm (MD) Top (TVD) Btm (TVD) FT Datefflsoolaed 6,084' 6,136' 5,595' 5,642' 52' 6,574' 6,638' 6,040' 6,098' 64' d 6,659' 6,677' 6,117' 6,134' 18' d 6,746' 6,772' 6,197' 6,221' 26' d 6,845' 6,857' 6,288' 6,299' 12' d 6,870' 6,881' 6,311' 6,321' 11' d7157' 7,230'dd jKK 7,905' 7,928' 71275' 7,295' 23' 08/07/19 Open 7,965' 7,300' 7,327' 31' 08/07/19 Open ±8,630' ±7,767' ±7,802' ±51' Future Proposed 8,733' 7,858' 7,870' 18' 11/09/18 Open l7,934' 8,795' 7,882' 7912' 45' 11/09/18 Open 9,018' 7,928' 8,061' 198' 11/09/18 Open 9,312' 8,074' 8,251' 274' 11/09/18 Open 9,480' 8,285' 8,354' 113' 11/09/18 Open 9,497' 9,790' 8,364' 8,Sa5 293 11/09/18 Open 9,824'1 10,015' 1 81566 6jo5' 1191' 11/09/18 Open HK -3 West (Repeat) 10,530' 1 10,666' 9,029' 9,134' 136' 11/03/18 Isolated Slotted Liner: HK -3 to HK -1 West (Repeat) 1 10,743' 1 12,045' 19,192'1 1,302' 1 11/03/18 Isolated Updated By: JLL02/20/20 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS SEP r u 1. Operations Abandon L Plug Perforations L Fracture Stimulate L Pull Tubing L 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: ❑ 2. Operator 4. Well Class Before Work: 5. Permitto Drill Number: Name: Hilcorp Alaska, LLC Development Q Stratigraphic ❑ Exploratory ❑ Service ❑ 195-119 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20179-03-00 7. Property Designation (Lease Number): 8, Well Name and Number: ADLO18754 MGS A41A-11 RD2 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Middle Ground Shoal / Middle Ground Shoal Oil Pool 11. Present Well Condition Summary: Total Depth measured 12,047 feet Plugs measured 10,226&±10,236 feet true vertical 10,045 feet Junk measured N/A feet Effective Depth measured 10,226 feet Packer measured 7,827 feet true vertical 8,815 feet true vertical 7,206 feet Casing .Length Size MD TVD Burst Collapse Structural Conductor 330' 24" 330' 330' Surface 1,990' 13-3/8" 1,990' 1,934' 3,090 psi 1,540 psi Intermediate 7,765' 7" 7,765' 7,148' 7,240 psi 5,410 psi Liner 5,089' 5" 10,743' 9,192' 13,940 psi 13,450 psi Liner 1,365' 3-1/2" 12,045' 10,041' Slotted Slotted Perforation depth Measured depth 7,905 - 10,015 feet True Vertical depth 7,275 - 8,682 feet 2-7/8" 6.5 / L-80 5,639 (MD) 5,195 (TVD) Tubing (size, grace, measured and true vertical depth) 2-3/8" 4.7 / L-80 7,903 (TVD) 7,273 (TVD) 7,827 (MD) 341 (MD) Packers and SSSV (type, measured and true vertical depth) MFH 15-18# Hyd Pkr 7,206 (TVD) Halliburton TRSV SCSSV 341 (TVD) 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: 5 1 i 72 653 86 Subsequent to operation: 15 3 145 1590 104 14. Attachments (required per 20 MC 25.070, 25.071, 825.293) 15. Well Class after work: Daily Report of Well Operations I] Exploratory ❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑' Gai__] ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUS[—] SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-334 Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe(a)hilcoro.com Authorizetl Signature: 1..-� j'v.�a ( Date: Contact Phone: (907) 283-1329 Form 10404 Revised 4/2017 q-6-11 RBDWNEP 0 5 2010 Submit Original Only aSCHEMATIC Hilcorp Alaska, I.LC KB: 38', KB to MSL:116', M51 -to Medline: 73' 5„ 1 1 I I 02/19/2006 Fill Lal 11,988' Ma_ 3-1/2" PBTD=12,045' TD =12,047' Middle Ground Shoal Well: MISS A41A-11RD2 Last Completed: 11/13/2018 PTD: 195-119 API: 50-733-20179-03 CASING DETAIL Size Wt Grade Cann ID Tap Btm Cement 24" Driven ConductorWelded Top (TVD) Hanger CIW-DCB-FBB,11'x3 X" EUE lift & susp w/3" Type "H" BPV profile Surf 330' N/A 13-3/8" 61 K-55 STC 12.515" Surf 178' 810 sx & Stop K-55 BTC 12.515" 178' 1,038' 2 54.5 K-55 BTC 12.615" 1,038' 1,080' 170 4,462'4.750 68 K-55BTC GLM#3-2-7/8" Weatherford SFO -1 12.415" 1,080' 1,990' job) 26 N-80 BTC 6.276" Surf 801' GLM#4-2-3/8"BST Lift Systems,GLMAT-1HP Slim hole, T-1 latch 5-95 LTC 6.276" 801' 1,547' 7" 5,92fi'3.500 N-80 LTC 6.184" 1,547' 5,224' 824 sx 29 S-95 LTC 6.184" 5,224' 5,686' L-80 LTC 6.184" 5,686' 7,765' S. 18 P-110 STL 4.276" 5,654' 10,743' 560 sx 3'1/2 (slotted) 9.3 J-55 BTC 2.992" 10,680' 12,045' N/A I UBING DETAIL 2-7/8" 6.5 L-80 8rtl EUE 2.441" Surf 5,639' 2-3/8" 4.7 L-80 I 8rd EUE 1 1.995" 1 5,639' 7,903' JEWELRY DETAIL No Depth (MD) Dep h (TVD) ID DD Item 38' 38' Btm (MD) Top (TVD) Hanger CIW-DCB-FBB,11'x3 X" EUE lift & susp w/3" Type "H" BPV profile 1 341' 341' 1 2.313 1 4.650 1 SCSSV- Halliburton TRSV NE 5,595' 1,889' 1,842'%2.4414.750 Isolated GLM#1-2-7/8" Weatherford SFO -1 2 3,509 3,321'4.750 6,098' 64' GLM#2-2-7/8" Weatherford SFO -1 Isolated 4,800' 4,462'4.750 6,677' 6,117' GLM#3-2-7/8" Weatherford SFO -1 3 5,639' 5,195'3.668 B6,746' X -Over to 2-3/8" 6,197' 5,774' 5,316'3.500 Isolated GLM#4-2-3/8"BST Lift Systems,GLMAT-1HP Slim hole, T-1 latch 46,449' 6,857' 5,92fi'3.500 6,299' 12' GLM#5-2-3/8"BST Lift Systems,GLMAT-1HP Slim hole, T-1 Latch Isolated 7,085' 6,510'3.500 6,881' 6,311' GLM#6-2-3/8"BST Lift Systems,GLMAT-1HP Slim hole, T-1 Latch 11' 7,731' 7,116'3.500 C 7,157' GLM#7(Orifice)-2-3/8"BST Lift Systems,GLMAT-1HP Slim hole, T-1 Latch 5 7,778' 7,160'3.500 Isolated Chemical Injection Mandrel -GLMATCI-1HP 6 7,827' 7,206' 1 1.929 4.070 Packer - MFH 15-18# Hydraulic Retrievable w/ 30k lb shear release 7 7,872' 7,246' 1.875 3.063 X Nipple 8 7,903' 7,273' 1.995 3.063 WLEG 9 10,226' 8,815' 08/07/19 Open CIBP 10 ±10,236' ±8,821' 7,870' 18' CIBP(partially set Cl8P) Updated By:JLL08/27/19 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Stm (TVD) FT Date Status A-1 6,084' 6,136' 5,595' 5,642' S2' Isolated B 6,574' fi,638' 6,040' 6,098' 64' Isolated B 6,659' 6,677' 6,117' 6,134' 18' Isolated B6,746' 6,772' 6,197' 6,221' 26' Isolated C 6,845' 6,857' 6,288' 6,299' 12' Isolated C 6,870' 6,881' 6,311' 6,321' 11' Isolated C 7,157' 7,230' 6,577' 6,645 73' Isolated C 1 7,251' 1 7,289' 1 6,665' 6,701' 38' Isolated F1 7,905' 7,928' 7 275' 7,295' 23' 08/07/19 Open F1 7,934' 7,9fi5' 7,300' 7,327' 31' 08/07/19 Open HK2 1 8,715' 8,733' 7,858' 7,870' 18' 11/09/18 Open HK2 8,750' 8,795' 7,882' 7,912' 45' 11/09/18 Open HK2 8,820' 9,018' 7,928' 8,061' 198' 11/09/18 Open HK2 9,038' 9,312' 8,074' 8,251' 274' 11/09/18 Open HK3 9,367' 9,480' 8,285' 8,354' 113' 11/09/18 Open HK3 [HK 9,497' 9,790' 8,364' 8,545' 293' 11/09/18 Open HK3 9,824' 10,015' 8,566' 8,682' 191' 11/09/18 Open HK -3 West IF 10,530' 10,666' 9,029' 9,134' 136' 11/03/18 Isolated Slotted Liner: -3 to HK -1 West (Repeat) 10,743' 12,045' 9,192' 10,041' 1,302' 1 11/03/18 1 solated Updated By:JLL08/27/19 HHilcorp Alaska, LLC Hil�rorp Alaxka, ��.� Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MGS A41A-11RD2 Eline 50-733-20179-03 195-119 8/7/2019 8/7/2019 Daily Operations: 08/07/2019- Wednesday P1SM. R/U on A41A-11RD2. M/U & test Gamma ray, CCL, and 19ft of perf guns. Pressure test lubricator and associated equipment to 250psi low / 2500 psi high per AOGCC Sundry. TEST GOOD. RIH w/ Gamma ray, CCL, and 19ft of 1.6875" retrievable Geo Razor perf guns. 6 SPF, 60 deg phasing, 3.2g . Log from 8160 to 7700ft. Correlated logs with town and shifted up 22ft. Correlate on depth and perforate 7965- 79466 (19FT) with well flowing, POOH. All shots fired. M/U & RIH w/ Gamma ray, CCL, and 12ft of 1.6875" retrievable Geo Razor perf guns. 6 SPF, 60 deg phasing, 3.2g. Correlate on depth and perforated 7946-7934ft (12FT) with well flowing, POOH. All shots fired. M/U & RIH w/ Gamma ray, CCL, and 23ft of 1.6875" retrievable Geo Razor perf guns. 6 SPF, 60 deg phasing, 3.2g. Correlate on depth and perforated 7928 7905ft (23FT) with well flowing, POOH. All shots fired. L/D spent guns. 08/08/2019 - Thursday 08/09/2019 - Friday 08/10/2019 -Saturday 08/11/2019 -Sunday 08/12/2019- Monday 08/13/2019 -Tuesday THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Stan Golis Operations Manager Hilcorp Alaska, LLC. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax 907.276.7542 www. a ogc c. a la ska. gov Re: Middle Ground Shoal Field, Middle Ground Shoal Oil Pool, MGS A41A-11RD2 Permit to Drill Number: 195-119 Sundry Number: 319-334 Dear Mr. Golis: 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, 4111114�� Daniel T. Seamount, Jr. Commissioner DATED this _ d�July, 2019. RBDM 45- jUL 2 61019 �I 'C U STATE OF ALASKA JUL 1 7 7619 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS �� 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑r 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 Q ' Stratigraphic ❑ Service ❑ 195-119 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20179-03-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 44A Will planned perforations require a spacing exception? Yes ❑ No ❑✓ MGS A41A-11 RD2 - 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018754 I Middle Ground Shoal / Middle Ground Shoal 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): 12,047 10,045 10,226 8,815 2,439 psi 10,226 & ±10,236 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 330' 24" 330' 330' Surface 1,990' 13-3/8" 1,990' 1,934' 3,090 psi 1,540 psi Intermediate 7,765' 7" 7,765' 7,148' 7,240 psi 5,410 psi Liner 5,089' 5" 10,743' 9,192' 13,940 psi 13,450 psi Liner 1,365' 3-1/2" 112,045' 10,041' 1 slotted slotted Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8,715 - 10,015 7,858 - 8,682 2-7/8" & 2-3/8" 6.5 / L-80 & 4.7 / L-80 7,903 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): MFH 15-18# Hyd Pkr & Halliburton TRSV SCSSV 7,827 (MD) 7,206 (TVD) & 341 (MD) 341 (ND) 12. Attachments: Proposal Summary ❑✓ Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/30/2019 OIL .r❑ • 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: dmarlowe@-hilcorp.com \ Contact Phone: (907) 283-1329 �..+ Authorized Signature: W Date: � � (e I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ^ �� /✓, Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS�14MUL 2 6 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No E Subsequent Form Required: /0—'/403/ APPROVED BY Approved by:�01 COMMISSIONER THE COMMISSION Date: (�^ YG �(>"O !/ 1\ 6 l 1 1 1 V /..?1 1 SubmR Form and Form 10-403 R ed 4/2017 pproved applicati i v li 1 o he data Of ap I� ��A" hmenis in uplicate / ,P1 ",7,�z�C 'ley 7-r7./i n ail�,p AI.A , LLC Well Prognosis Well Name: MGS A41A-11rd2 API Number: 50-733-20179-03 Current Status: Gas -Lifted producer Leg: Leg #2 Estimated Start Date: 7/30/2019 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 195-119 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907) 777-8356 (0) (281) 450-3071 (M) Current Bottom Hole Pressure: 3,225 psi @ 7,858' TVD 0.410 lbs/ft (7.89 ppg) Maximum Expected BHP (Hemlock): 3,225 psi @ 7,858' TVD 0.410 lbs/ft (7.89 ppg) Maximum Potential Surface Pressure: 2,439 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary The Middle Ground Shoal A41A-11rd2 is currently producing from the Hemlock 2, & 3 sands with very limited inflow. This project will add perforations in the F sands. Procedure: 1. MIRU E -line, PT lubricator to 2,500 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 n Hilmru Alaska, LLC KB: 38'. KB to MSL: 116'. MSL to Mudline: 73' ' I I I I I I I I I I I 102/19/2006 FII @ 1 111,988' 1 r 3-1/2 PBTD = 12,045' TD =12,047' SCHEMATIC Middle Ground Shoal Well: MGS A41A-11RD2 Last Completed: 11/13/2018 PTD: 195-119 API: 50-733-20179-03 CASING DETAIL Size Wt I Grade Conn ID Top Btm Cement 24" Driven Conductor Welded Hanger CIW-DCB-FBB, 11'x3 Y:" EUE lift & susp w/3" Type "H" BPV profile Surf 330' N/A 2.313 4.650 K-55 STC 12.515" Surf 178' 810sx& 61 K-55 BTC 12.515" 178' 1,038' 13-3/8" 54.5 K-55 BTC 12.615" 1,038' 1,080' 170 sx 4,462' 68 K-55 BTC 12.415" 1,080' 1,990' ([opjobob) 3.668 X -Over to 2-3/8" N-80 BTC 6.276" Surf 801' GLM#4-2-3/8"BST Lift Systems,GLMAT-1HP Slim hole, T-1 Latch 26 S-95 LTC 6.276" 801' 1,547' 7" 5,926' N-80 LTC 6.184" 1,547' 5,224' 824 sx 29 5-95 LTC 6.184" 5,224' 5,686' L-80 LTC 6.184" 5,686' 7,765' 5" 18 P-110 STL 4.276" 5,654' 10,743' 560 sx (slotted) 7,160' J-55 BTC 2.992" 10,680' 12,045' N/A TUBING DETAIL 2-7/8" 6.5 L-80 8rd EUE 2.441" Surf 5,639' 2-3/8" 4.7 L-80 8rd EUE 1.995" 5,639' 7,903' JEWELRY DETAIL No Depth (M D) Depth (TVD) ID OD Item Zone 38' 38' Top (TVD) Btm (TVD) Hanger CIW-DCB-FBB, 11'x3 Y:" EUE lift & susp w/3" Type "H" BPV profile 1 341' 341' 2.313 4.650 SCSSV- Halliburton TRSV NE 5,642' 1,889' 1,842' 2.441 4.750 GLM #1-2-7/8" Weatherford SFO -1 2 3,509 3,321' 2.441 4.750 GLM#2-2-7/8"Weatherford SFO -1 B 4,800' 4,462' 2.441 4.750 GUM #3-2-7/8"Weatherford SFO -1 3 5,639' 5,195' 1.995 3.668 X -Over to 2-3/8" 6,221' 51774' 51316' 1.995 3.500 GLM#4-2-3/8"BST Lift Systems,GLMAT-1HP Slim hole, T-1 Latch 6,857' 6,449' 5,926' 1.995 3.500 GLM#5-2-3/8"BST Lift Systems,GLMAT-1HP Slim hole, T-1 Latch 4 7,085' 6,510' 1.995 3.500 GUM #6-2-3/8"BST Lift Systems,GLMAT-1HP Slim hole, T-1 Latch 7,731' 7,116' 1.995 3.500 GLM#7(Orifice)-2-3/8'BST Lift Systems, GLMAT-iHP Slim hole, T-1 Latch 5 7,778' 7,160' 1.995 3.500 Chemical Injection Mandrel-GLMATCI-1HP 6 7,827' 7,206' 1.929 4.070 Packer- MFH 15-18# Hydraulic Retrievable w/ 30k Ib shear release 7 7,872' 7,246' 1.875 3.063 X Nipple 8 7,903' 7,273' 1.995 3.063 WLEG 9 10,226' 8,815' Open HK2 CIBP 10 ±10,236' ±8,821' 198' 11/09/18 CIBP(partially set CIBP) Updated By: JLL 11/21/18 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status A-1 6,084' 6,136' 5,595' 5,642' 52' Isolated B 6,574' 6,638' 6,040' 6,098' 64' Isolated B 6,659' 6,677' 6,117' 6,134' 18' Isolated B 6,746' 6,772' 6,197' 6,221' 26' Isolated C 6,845' 6,857' 6,288' 6,299' 12' Isolated C 6,870' 6,881' 6,311' 6,321' 11' Isolated C 7,157' 1 7,230' 6,577' 1 6,645' 73' 1 1 Isolated C 7,251' 7,289' 6,665' 6,701' 38' Isolated HK2 8,715' 8,733' 7,858' 7,870' 18' 11/09/18 Open HK2 8,750' 8,795' 7,882' 7,912' 45' 11/09/18 Open HK2 8,820' 9,018' 7,928' 8,061' 198' 11/09/18 Open HK2 9,038' 9,312' 8,074' 8,251' 274' 11/09/18 Open HK3 9,367' 9,480' 8,285' 8,354' 113' 11/09/18 Open HK3 9,497' 9,790' 8,364' 8,545' 293' 11/09/18 Open HK3 9,824' 10,015' 8,566' 8,682' 191' 11/09/18 Open HK -3 West (Repeat) 10,530' 10,666' 9,029' 9,134' 136' 11/03/18 Isolated Slotted Liner: HK -3 to HK -1 West (Repeat) 10,743' 12,045' 1 9,192' 1 10,041' 1,302' 1 11/03/18 Isolated Updated By: JLL 11/21/18 H HJloorp Alaska, LLC KB:38'. KB to MSL: 116'. M5L to Mud line: 73' I I I I I 1 I I I I 102/19/2006 Fill @ i 111,988' 1 PBTD =12,045' TD =12,047' PROPOSED Middle Ground Shoal Well: MGS A41A-11RD2 Last Completed: 11/13/2018 PTD: 195-119 AN: 50-733-20179-03 CASING DETAIL Size Wt Grade Conn 10 Top Btm Cement 24" Driven Conductor Welded Hanger CIW-DCB-FBB, 11'x3 %" EUE lift & susp w/3" Type "H" BPV profile Surf 330' N/A 2.313 4.650 K-55 STC 12.515" Surf 178' 810 sx & 61 K-55 BTC 12.515" 178' 1,038' 13-3/8" 54.5 K-55 BTC 12.615" 1,038' 1,080' 170 sx (top 4,462' 68 K-55 BTC 12.415" 1,080' 1,990' Job) 3.668 K -Over to 2-3/8" N-80 BTC 6.276" Surf 801' GLM k4- 2-3/8" BST Lift Systems, GLMAT-1HP Slim hole, T-1 Latch 26 S-95 LTC 6.276" 801' 1,547' 7" 5,926' N-80 LTC 6.184" 1,547' 5,224' 824 sx 29 S-95 LTC 6.184" 5,224' 5,686' L-80 LTC 6.184" 5,686' 7,765' 5" 18 P-110 TTL 4.276" 1 5,654' 10,743 560 sx 3-1/2" (slotted) 9.3 1-55 BTC 2.992" 10,680' 12,045' N/A TUBING DETAIL 2-7/8" 6.5 L-80 8rd EUE 2.441" Surf 5,639' 2-3/8" 4.7 L-80 8rd EUE 1 1.995" 5,639' 7,903' JEWELRY DETAIL No (MD) 'ND' ID OD Item 38' 38' Btm (MD) Top (TVD) Hanger CIW-DCB-FBB, 11'x3 %" EUE lift & susp w/3" Type "H" BPV profile 1 341' 341' 2.313 4.650 SCSSV- Halliburton TRSV NE 5,595' 1,889' 1,842' 2.441 4.750 GLM Nl-2-7/8"Weatherford SFO -1 2 3,509 3,321' 2.441 4.750 GLM N2- 2-7/8" Weatherford SFO -1 Isolated 4,800' 4,462' 2.441 4.750 GLM M3-2-7/8"Weatherford 5FO-1 3 5,639' 5,195' 1.995 3.668 K -Over to 2-3/8" 6,197' 5,774' 5,316' 1.995 3.500 GLM k4- 2-3/8" BST Lift Systems, GLMAT-1HP Slim hole, T-1 Latch 6,845' 6,449' 5,926' 1.995 3.500 GLM p5-2-3/8"BST Uft Systems, GLMAT-iH P Slim hole, T-1 Latch 4 7,085' 6,510' 1.995 3.500 GLM k6-2-3/8"EST Lift Systems, G LMATAH P Slim hole, T-1 Latch 11' 7,731' 7,116' 1.995 3.500 GLM #7 (Orifice) -2-3/8" BST Lift Systems, GLMAT-1HP Slim hole, T-1 Latch 5 7,778' 7,160' 1.995 3.500 Chemical Injection Mandrel- GLMATCI-1HP 6 7,827' 7,206' 1.929 4.070 Packer- MFH 15-18N Hydraulic Retrievable w/ 301, Ib shear release 7 7,872' 7,246' 1.875 3.063 K Nipple 8 7,903' 7,273' 1.995 3.063 WLEG 9 10,226' 8,815' Future Proposed CIBP 30 ±10,236' ±8,821' 7,870' 18' CIBP (partially set CIBP) Updated By: JLL 07/10/19 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status A-1 6,084' 6,136' 5,595' 5,642' 52' Isolated B 6,574' 6,638' 6,040' 6,098' 64' Isolated B 6,659' 6,677' 6,117' 6,134' 18' Isolated B 6,7461 6,772' 6,197' 6,221' 26' Isolated C 6,845' 6,857' 6,288' 6,299' 12' Isolated C 6,870' 6,881' 6,311' 6,321' 11' Isolated C 7,157' 7,230' 6,577' 6,645' 73' Isolated C 7,251' 7,289' 6,665' 6,701' 38' Isolated F1 ±7,905' ±7,928' ±7,275' ±7,295' ±23' Future Proposed F1 ±7,934' ±7,965' ±7,300' ±7,327' ±31' Future Proposed HK2 8,715' 8,733' 7,858' 7,870' 18' 11/09/18 Open HK2 8,750' 8,795' 7,882' 7,912' 45' 11/09/18 Open HK2 8,820' 9,018' 7,928' 8,061' 198' 11/09/18 Open HK2 9,038' 9,312' 8,074' 8,251' 274' 11/09/18 Open HK3 9,367' 9,480' 8,285' 8,354' 113' 11/09/18 Open HK3 9,497' 9,790' 8,364' 8,545' 293' 11/09/18 Open HK3 9,824' 10,015' 8,566' 8,682' 191' 11/09/18 Open HK -3 West (Repeat) 10,530' 10,666' 9,029' 9,134' 136' 11/03/18 Isolated Slotted Liner: HK -3 to HK -1 West (Repeat) 10,743' 1 12,045' 1 9,192' 10,041' 1 1,302' 11/03/18 Isolated Updated By: JLL 07/10/19 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 11eGl✓GI V GV APR 0 8 2019 1. Operations Abandon Plug Perforations Fracture Stimulaf Pull Tubing Operations shutdownLi Performed: Suspend ❑ Perforate ❑ Other Stimulat0 Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair We❑ Re-enter Susp Well ❑ Other: Oil Safe AR Acid ❑✓ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development Q Exploratory ❑ Stratigraphic ❑ Service ❑ 195-119 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20179-03-00 7. Property Designation (Lease Number): B. Well Name and Number: ADLO18754 MGS A41A-11 RD2 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 and Middle Ground Shoal Oil Pools 11. Present Well Condition Summary: Total Depth measured 12,047 feet Plugs measured 10,226&J:10,236 feet true vertical 10,045 feet Junk measured N/A feet Effective Depth measured 10,226 feet Packer measured 7,827 feet true vertical 8,815 feet true vertical 7,206 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 330' 24" 330' 330' Surface 1,990' 13-3/8" 1,990' 1,934' 3,090 psi 1,540 psi Intermediate 7,765' 7" 7,765' 7,148' 7,240 psi 5,410 psi Liner 5,089' 5" 10,743' 9,192' 13,940 psi 13,450 psi Liner 1,365' 3-1/2" 12,045' 10,041' Slotted Slotted Perforation depth Measured depth 8,715 - 10,015 feet True Vertical depth 7,858 - 6,682 feet 2-7/8" 6.5 / L-80 5,639 (MD) 5,195 (TVD) Tubing (size, grade, measured and true vertical depth) 2-3/8" 4.7 / L-80 7,903 (TVD) 7,273 (TVD) 7,827 (MD) 341 (MD) Packers and SSSV (type, measured and true vertical depth) MFH 15-18# Hyd Pkr 7,206 (TVD) Halliburton TRSV SCSSV 341 (ND) 12. Stimulation orcement squeeze summary: Intervals treated (measured): 8,715 - 10,015 Treatment descriptions including volumes used and final pressure: Pumped 5,775 gallons OilSafe AR acid and 47 bbls FIW. Final pressure 295#. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 10 5 65 1 612 80 Subsequent to operation: 1 4 63 667 95 14. Attachments (required per 20 AAC 25.070, 25071, & 25.263) 15. Well Class after work: Daily Report of Well Operations Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil L�sJ GaLl WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUS❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-069 Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmadowe@hilcom.com Authorized Signature: f Q^ 'D �p Date: l Contact Phone: (907) 283-1329 Form 10-404 Revised 4/2017 RBDMSI±4PR 0 9 2019 Submit Original Only KB: 38', KB to MSL: 116', MSL to Mudline: 73' 5 I I I I I I I I I I I 102/19/200fi Fill@ 1 111,988' 1 3'1/2" ,.M =.:.,,.:. PBTD =12,045' TO =12,047' Middle Ground Shoal Well: MISS A41A-11RD2 Last Completed: 11/13/2018 SCHEMATIC PTD: 195-119 API: 50-733-20179-03 CASING DETAIL Size Wt I Grade Conn ID Top Btm Cement 24" Driven Conductor Welded Hanger CIW-DCB-FBB, 11'x3 Y" EUE lift & susp w/3" Type "H" BPV profile Surf 330' N/A 2.313 4.650 K-55 STC 12.515" Surf 178' 810 sx & 61 K-55 BTC 12.515" 178' 11038' 13-3/8" 54.5 K-55 BTC 12.615" 1,038' 1,080' 170 sx 4,462' 68 K-55 BTC 12.415" 11080' 1,990' ([op job) 3.668 26 N-80 BTC 6.276" Surf 801' -X-Over GLM 94 -2-3/8" BST Lift Systems, GLMAT-1HP Slim hole, T-1 Latch S-95 LTC 6.276" 801' 1,547' 7" 5,926' N-80 LTC 6.184" 1,547' 5,224' 824 sx 29 5-95 LTC 6.184" 5,224' 5,686' L-80 LTC 6.184" 5,686' 7,765' 5" 18 P-110 STL 4.276" 5,654' 10,743' 560 sx (slotted) 7,160' J-55 BTC 2.992" 10,680' 12,045' N/A TUBING DETAIL 2-7/8" 6.5 L-80 8rd EUE 2.441" Surf 5,639' 2-3/8" 4.7 L-80 8rd EUE 1 1.995" 5,639' 7,903' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item Zone 38' 38' Top (TVD) Btm (TVD) Hanger CIW-DCB-FBB, 11'x3 Y" EUE lift & susp w/3" Type "H" BPV profile 1 341' 341' 2.313 4.650 SCSSV- Halliburton TRSV NE 5,642' 1,889' 1,842' 2.441 4.750 GUM #1-2-7/8"Weatherford SFO -1 2 3,509 3,321' 2.441 4.750 GLM #2 - 2-7/8" Weatherford SF0-1 B 4,800' 4,462' 2.441 4.750 GUM #3-2-7/8'Weatherford SF0-1 3 5,639' 5,195' 1.995 3.668 to 2-3/8" 6,221' 5,774' 5,316' 1.995 3.500 -X-Over GLM 94 -2-3/8" BST Lift Systems, GLMAT-1HP Slim hole, T-1 Latch 6,857' 6,449' 5,926' 1.995 3.500 GLM #5-2-3/8" BST Lift Systems, GLMAT-1HP Slim hole, T-1 Latch 4 7,085' 6,510' 1.995 3.500 GLM #6-2-3/8" BST Lift Systems, GLMAT-1HP Slim hole, T-1 Latch 7,731' 7,116' 1.995 3.500 GLM #7 (Orifice) -2-3/8" BST Lift Systems, GLMAT-1HP Slim hole, T-1 Latch 5 7,778' 7,160' 1.995 3.500 Chemical Injection Mandrel -GLMATCI-1HP 6 7,827' 7,206' 1.929 4.070 Packer -MFH 15-18# Hydraulic Retrievablew/30k lbshearrelease. 7 7,872' 7,246' 1.875 3.063 X Nipple 8 7,903' 7,273' 1.995 3.063 WLEG 910,226' 45' 8,815' Open HK2 CIBP 10 110,236' 18,821' 198' 11/09/18 CIBP(partially set CIBP) Updated By: JUL 11/21/18 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status A-1 6,084' 6,136' 5,595' 5,642' 52' Isolated B 6,574' 6,638' 6,040' 6,098' 64' Isolated B 6,659' 6,677' 6,117' 6,134' 18' Isolated B 6,746' 6,772' 6,197' 6,221' 26' Isolated C 6,845' 6,857' 6,288' 6,299' 12' Isolated C 6,870' 6,881' 6,311' 6,321' 11' Isolated C 7,157' 1 7,230' 6,577' 1 6,645' 73' Isolated C 7,251' 1 7,289' 6,665' 6,701' 38' Isolated HK2 8,715' 8,733' 7,858' 7,870' 18' 11/09/18 Open HK2 8,750' 8,795' 7,882' 7,912' 45' 11/09/18 Open HK2 8,820' 9,018' 7,928' 8,061' 198' 11/09/18 Open HK2 9,038' 9,312' 8,074' 8,251' 274' 11/09/18 Open HK3 9,367' 9,480' 8,285' 8,354' 113' 11/09/18 Open HK3 9,497' 9,790' 8,364' 8,545' 293' 11/09/18 Open HK3 9,824' 10,015' 8,566' 8682'191, 11/09/18 Open HK -3 West (Repeat) 10,530' 10,666' 9,029' 9,134' 136' 11/03/18 Isolated Slotted Liner: HK -3 to HK -1 West (Repeat) 1 10,743' 1 12,045' 1 9,192' 10,041' 1,302' 11/03/18 Isolated Updated By: JUL 11/21/18 HHilcorp Alaska, LLC Hilcorp Alnaka, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MGS A41A-11RD2 Pumping Unit 50-733-20179-03 195-119 3/17/2019 3/17/2019 Daily Operations: 03/17/2019 -Sunday Pre job safety meeting and rig up. Wing and Injection valves shut, pressure test to 2000#. Double check that valves are shut in and skid is ready to begin pumping. Pumping tote #1/6 safe acid tbg – 80, IA -210, OA -14. Shutdown pump to change out valve and go to bigger air line. Pump tote #2/6 safe acid. Tbg – 85, IA – 575, IA- 14. Pump tote #3/6 safe acid. Tbg- 0, IA -574, OA -14. Pump tote #4/6 safe acid. Tbg-0, IA -574, OA -14. Pump tote #5/6 safe acid. Tbg-0, IA -573, OA -14. Pump tote #6/6 safe acid. TBG -0, IA -571, OA -14. Pump tote #1/7 FIW. Tbg-0, IA -571, OA -14. Pump tote #2/7 FIW. Tbg-0, IA -572, OA -14. Pump tote #3/7 FIW. Tbg-0, IA -572, OA -14. Pump tote #4/7 FIW. Tbg-190, IA -572, OA -14. Pump tote #5/7 FIW. Tbg-300, IA- 572, OA -14. Pump tote #6/7 FIW. Tbg-330, IA -574, OA -14. Pump tote #7/7 FIW. Tbg-260, IA -585, OA -14. Done pumping (47 bbls) FIW. Tbg-295, IA -597, OA -14. THE STATE OfALASKA GOVERNOR MIKE DUNLEAVY Stan W. Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 W ww.aogc c. olaska.gov Re: Middle Ground Shoal Field, E, F, G and MGS Oil Pools, MGS A41A-I 1RD2 Permit to Drill Number: 195-119 Sundry Number: 319-069 Dear Mr. Golis: 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, 10 Daniel T. Seamount, Jr. Commissioner DATED this ZUday of February, 2019. RBDMS FEB 2 01019 sECE—EED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 12 2019 APPLICATION FOR SUNDRY APPROVALS on aar 06 oon 1. Type of Request: Abandon El Plug Perforations ❑ `Fracture Stimulate ❑ Repair Well ❑ 'Operations shutdown ❑ Suspend El Perforate EJOthar timucIVlate Q Pull Tubing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susie Well ❑ Alter Casing ❑ Othe CA`_�^ A k 2. Operator Name: 4. Current Well Class: mit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development 19 3. Address: 3800 Cenlerpoint Drive, Suite 1400 Stratigraphic ❑ Service Number: JE Anchorage, AK 99503 3-20179-03-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? WA Will planned perforations require a spacing exception? Yes ❑ ❑� No MGS A41A-11 RD2 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018754 I Middle Ground Shoal / E,F and G Oil &Middle Ground Shoal Oil Pools+ 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): 12,047 10,045 10,226 8,815 t5,000psi 10,226&±10,236 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 330' 24" 330' 330' Surface 1,990' 13-3/8" 1,990' 1,934' 3,090 psi 1,540 psi Intermediate 7,765' 7" 7,765' 7,148' 7,240 psi 5,410 psi Liner 5,089' 5" 10,743' 9,192' 13,940 psi 13,450 psi Liner 1 1,365' 3-1/2" 12,045' 10,041' Slotted Slotted Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8,715 - 10,015 7,858 - 8,682 2-7/8" & 2-3/8" 6.5 / L-80 & 4.7 / L-80 5,639 8 7,903 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): MFH 15-18# Hyd. Packer & Halliburton TRSV SCSSV 7,827 (MD) 7,206 (TVD) & 341 (MD) 341 (TVD) 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/15/2019 OIL ❑✓ 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: dlnarlowe hilcor .Com Contact Phone: (907) 283-1329 Authorized Signature: � 2.1 17, Date: ( 9 COMMISSION USE ONLY t Conditions of approval: Notify Commissions No that a representative may witness Sundry Number: I (XQq Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ 9 Y ❑ Location Clearance Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved2 %'LO / A by: COMMISSIONER THE l COMMISSION Date: I ` ti r� / _ R■ .'r�„ `,`� Lt�.e Submt Form an d�/��Oml 10403 Revised 4/2017 Approved �applicatiVsR11fe2ft FEU Z O ZIchmenls in Duplica i4111 or tW /y ff aam.r. ". LLC Well Prognosis Well Name: MGS A41A-11rd2 API Number: 50-733-20179-03 Current Status: Gas -Lifted producer Leg: Leg #2 Estimated Start Date: 3/15/2019 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 195-119 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Mike Quick (907) 777-8442 (0) (907) 317-2969 (M) Current Bottom Hole Pressure: 3,325 psi @ 7,858' TVD 0.410 lbs/ft (7.89 ppg) Maximum Expected BHP (Hemlock): 3,325 psi @ 7,858' TVD 0.410 lbs/ft (7.89 ppg) Maximum Potential Surface Pressure:±5,000 psi (treatment pump limit) Brief Well Summary The Middle Ground Shoal A41A-11rd2 is currently producing from the Hemlock 2, & 3 sands. This project will stimulate the well in an attempt to remediate suspected skin damage. ' Procedure: 1. MIRU pumping equipment. 2. Pressure test surface lines to ±5,000 psi (treatment pump limit). `t 3. Pump ±1,650gallons Oilsafe AR (synthetic acid) - - 1{p 4 4. Displace with ±41 bbls FIW 5. Shut down pump and let for±72 hours. 6. Rig down pumping equipment 7. Turn over to production Attachments: 1. Well Schematic Current 2. Fluid Flow Diagrams 3. OilsafeAR-Technical Data Sheet KB: 38', KB to MSL: 116', MSLto Mudline: 73' ' I I 1 I 1 I I I I I 102/19/2006 Fill@ 1 111,988' 1 3-1/2" PBTD = 12,045' TD =12,047' SCHEMATIC Middle Ground Shoal Well: MGS A41A-11RD2 Last Completed: 11/13/2018 PTD: 19S-119 API: 50-733-20179-03 CASING DETAIL Size Wt&K-55BTC Depth (TVD) nn ID Top Btm Cement 24" Drivlded Btm (TVD) Hanger CIW-DCB-FBB, 11'x3 Y" EUE lift & susp w/3" Type "H" BPV profile Surf 330' N/A 13-3/8" 61TC SCSSV-Halliburton TRSV NE 5,642' 12.515" Surf 178' 810 sx& TC 12.515" 178' 1,038' 2 54.5TC 3,321' 2.441 12.615" 1,038' 1,080' 1705x 4,462' 68TC 4.750 GUM #3-2-7/8"Weatherford SFO -1 12.415" 1,08U 1,990' (top job) 3.668 26TC 6,221' 5,774' 6.276" Surf 801' GLM #4 -2-3/8" BST Lift Systems, GLMAT-1HP Slim hole, T-1 Latch TC 6.276" 801' 1,547' 7" 1 5,926 N-80 LTC 6.184" 1,547' 5,224' 824 sx 29 S-95 LTC 6.184" 5,224' 5,686' L-80 LTC 6.184" 5,686' 7,765' 5" 18 P-110 STL 4.276" 5,654' 10,743' 560 sx (slotted) 9.3 J-55 BTC 2.992" 10,680' 12,045' N/A TUBING DETAIL 32L JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item Zone 38' 38' Top (TVD) Btm (TVD) Hanger CIW-DCB-FBB, 11'x3 Y" EUE lift & susp w/3" Type "H" BPV profile 1 341' 341' 2.313 4.650 SCSSV-Halliburton TRSV NE 5,642' 1,889' 1,842' 2.441 4.750 GLM#1-2-7/8"Weatherford SFO -1 2 3,509 3,321' 2.441 4.750 GLM#2-2-7/8"Weatherford SFO -1 8 4,800' 4,462' 2.441 4.750 GUM #3-2-7/8"Weatherford SFO -1 3 5,639' 5,195' 1.995 3.668 X -Over to 2-3/8" 6,221' 5,774' 5,316' 1.995 3.500 GLM #4 -2-3/8" BST Lift Systems, GLMAT-1HP Slim hole, T-1 Latch 6,857' 6,449' 1 5,926 1.995 3.500 GLM #5 -2-3/8" BST Lift Systems, GLMAT-lHP Slim hole, T-1 Latch 4 7,085' 6,510' 1.995 3.500 GLM #6- 2-3/8" BST Lift Systems, GLMAT-111P Slim hole, T-1 Latch 7,731' 7,116' 1.995 3.500 GLM #7 (Orifice) - 2-3/8" BST Lift Systems, GLMAT-1HP Slim hole, T-1 Latch 5 7,778' 7,160' 1.995 3.500 Chemical Injection Mandrel - GLMATCI-SHP 6 7,827' 7,206' 1.929 4.070 Packer- MFH 15-18# Hydraulic Retrievable w/ 30k Ib shear release 7 7 ,872' 7 ,246 1.875 3.063 X Nipple 8 7,903' 7,273' 1.995 3.063 WLEG 9 10,226' 8,815' Open HK2 CIBP 10 ±10,236' 1 ±8821' I I 11/09/18 I CIBP(partially set CIBP) Updated By: JILL 11/21/18 PERFORATION DETAIL Zone Btm (MD) Top (TVD) Btm (TVD) tatus A-1 6,136' 5,595' 5,642' olated B 6,638' 6,040' 6,098' olated 8 J(M 6,677' 6,117' 6,134' P73'IsolateLd olated B 6,772' 6,197' 6,221' olated C 6,857' 6288' 6299' olated C 6,881' 6,311' 6,321' olatedC , 7,230' 6,577' 6,645' C 7,251' 7,289' 6,665' 6,701' olated HK2 8,715' 8,733' 7,858' 7,870' 18' 11/09/18 Open HK2 8,750' 8,795' 7,882' 7,912' 45' 11/09/18 Open HK2 8,820' 9,018' 7,928' 8,061' 198' 11/09/18 Open HK2 9,038' 9,312' 8,074' 8,251' 274' 11/09/18 Open HK3 9,367' 9,480'8,285' 8,354' 113' 11/09/18 Open HK3 9,497' 9,790' 8,364' 8,545' 293' 11/09/18 Open HK3 9,824' 10,015' 8,566' 8,682' 191' 11/09/18 Open HK -3 West (Repeat) 10,530' 10,666' 9,029' 9,134' 136' 11/03/18 Isolated Slotted Liner: HK -3 to HKA West (Repeat) 10,743' 12,045' 9,192' 10,041' 1,302' 11/03/18 Isolated Updated By: JILL 11/21/18 —: e. —_ "' a3sv.3a ssw �+. amr mvvnvaa vnavaeav ue ws�m sa dvuw NaOM nam nevlaod VfOS a A3A W1SNI aNV ONIdW vdsn uvn sore 3WH&id0 131NI N000 dAU OIT xni xura Oil Safe AR® is a safe yet functional replacement for traditional hydrochloric acid treatments and other commonly used oMeld acid treatments. It is non-regulated by US DOT, Canadian TDG and carries a triple zero hazardous materials Information system score. OR Safe AR® biodegrades in10 days or less and is approved by the US EPA as a Designed for the Environment product. Our Standard Oil Safe AR®formula includes iron control agents, de-mulsieers and requires no organic acid additions or corrosion inhibitors under most conditions. FEATURES AND BENEFITS: • An excellent choice forfracs, spearhead treatments, Injection welband c1h. pwd coelia and armYlar sash • Requires lrgw eck acid addriom to help relardm..tkn rate. Standard formula Indudea mdaclant end de-mulemerryatem • Requires M iron control agent addition for most applications EPA WE formula; blcdagradable to 10 drys or lus; approved for direct dle- charge; made wUh Cleangredlente and R6 ingredient. approved by the EPA Safe on most metsb, piping and pumping.wIpment • NM toric, nM fanning; non mutageNe; no YOC'e • No secondary containment required as per Chapter 62-70IFA.C. Eliminale.bulanle An excellent choice for work -over projects, bullhead Ueabnenb and oement remediation • Requires lig addtdoml corrosion inhibitor step for most applications • log% blodegndahk. add free aduW.My inhibited DISSOLVING PROPERTIES ACID TYPE % CaCOe Cil Safe ARV60%Solution 96.76% OB Safe AR®30%Solution 84.00 7 %HCI 46.48% 16% HCI 87.39% TA HCI +100 gpt of 85% Acetic Acid 76.08% 15%HCI +100 gpt of 85% Acetic Acid 97.87% 10% Acetic Acid 91.00% 15%Acetic Acid 93.09% Shah lam obe—eas mrduotedwlN 1 cure lncholmalm at ploctdk an ml W eckeenmW eaoeed beomr fora hn.110 M. TYPICAL PHYSICAL PROPERTIES: DIRECTIONS FOR USE: Recommended Dilution Rales: 30-1000%with H'O based on the severity of the build-up and the reaction rate required for the project. Note: OB Safe AR® concentrate contains bon control agents and de-mulsifiers. No organic acid or corrosion hadbitors are required due to the power of our patented Syntech®. A typical ratio for an acid frac is one part Oil Safe AR® and one part H'O. Blending rating may very based on specific applications and recommendations from your consultants at Heartland Energy Group, Ltd. STORAGE AND HANDLING: Oil Safe ARG has a storage life ofbetter than one year. Keep container closed when not in use. As With all chemicalproducts and materials, take care. to where you store them. Safety glasses are suggested for me when handling this product. No special gloves or protective equipment are required when handling this product. When pumping this product, it is strongly recommended to use manufacturer approved hose couplings or fittings. DO NOT USE ALUMINUM FFITIUM. 316 Stainless Steel, polypropylene, polyethylene are recommended. PACKAGING: OR Safe AM is shipped in bulk tanker trucks from the manufacturing facility. Smaller packaging quantities are available upon request. ao—dende it.dis en N to M-reekobrobemdon-odd eoccde b<maltob Hoeerer,Na umclWelnhmuYonlrbeyvndtM1e sconce no onoPnegyCmuq Ild., andm guuenfee, er. promtlor(nrpaedbmadeb NemeulaoblematlUmluredN eavrdar¢e MNdineaenrwaahblUhedry puan.'lbebuyxrmmlaawmeaU mrponslDWry, LrNmneWurvertlemene Gom Ne STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS zzrJ RS F,sux V N� '.s :I�Ud li:ia D 1. Operations Abandon Plug Perforations LwJ Fracture Stimulate LJ Pull Tubing ✓ Operations shutdov/n Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CTCO & Convert to Producer ❑✓ 2. Operator 4. Well Class Before Work: 1 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development p ❑ Exploratory ❑ Stratigraphic ❑ Service ❑✓ 195-119 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20179-03-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018754 MGS A41 A-11 RD2 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 11. Present Well Condition Summary: Total Depth measured 12,047 feet Plugs measured 10,226&±10,236 feet true vertical 10,045 feet Junk measured N/A feet Effective Depth measured 10,226 feet Packer measured 7,827 feet true vertical 8,815 feet true vertical 7,206 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 330' 24" 330' 330' Surface 1,990' 13-3/8" 1,990' 1,934' 3,090 psi 1,540 psi Intermediate 7,765' 7" 7,765' 7,148' 7,240 psi 5,410 psi Liner 5,089' 5" 10,743' 9,192' 13,940 psi 13,450 psi Liner 1,365' 3-1/2" 12,045' 10,041' slotted slotted Perforation depth Measured depth 8,715 - 10,015 feet True Vertical depth 7,858 - 8,682 feet 2-7/8" 6.5 / L-80 5,639 (MD) 5,195 (TVD) Tubing (size, grade, measured and true vertical depth) 2-3/8" 4.7 / L-80 7,903 (MD) 7,273 (TVD) Packers and SSSV (type, measured and true vertical depth) MFH 15-18# SCSSV Hyd. Pur 7,827 (MD) 7,206 (TVD) Halliburton TRSV 341 (MD) 341 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 19 50 Subsequent to operation: 3 0 48 513 81 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 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 ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-391 Authorized Name: Stan W. Golfs Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarloweCa�hilcoro.com . Authorized Signature: w p Date: I Z 3 16 Contact Phone: (907) 283-1329 Form 10-404 Revised 4/2017 1 �/ �j —' 9 1J L RBDMSDEC Q C 91110 W/11 LYW Submit Original Only K Hil�rp Alaska, LLC K8: 38'. KB to MSL: 116', MSLto Mudline: 73' 6 I I I I I I I 1 I I I I I 02/19/2006 Fill @ 111,988' I PBTD =12,045' TD =12,047' SCHEMATIC Middle Ground Shoal Well: MISS A41A-11RD2 Last Completed: 11/13/2018 PTD: 195-119 API: 50-733-20179-03 CASING DETAIL Size Wt Grade Conn ID Top Btm Cement 24" Driven Conductor Welded Hanger CIW-DCB-FBB, 11'x3 %" EUE lift & susp w/3" Type "H" BPV profile Surf 330' N/A 13-3/8" 61 K-55 STC 12.515" Surf 178' 810 sx & K-55 BTC 12.515" 178' 1,038' 2 54.5 K-55 BTC 12.615" 1,038' 11080 170 sx 4,462' 68 K-55 BTC 12.415" 1,080' 1,990' (top job) 3.668 26 N-80 BTC 6.276" Surf 801' GUM #4-2-3/8'BST Lift Systems,GLMAT-1HP Slim hole, T-1 Latch S-95 LTC 6.276" 801' 1,547' 7" 5,926' N-80 LTC 6.184" 1,547' 5,224' 824 sx 29 5-95 LTC 6.184" 5,224' 5,686' L-80 LTC 6.184" 5,686' 7,765' 5" 18 P-110 STL 4.276" 5,654' 10,743' 560 sx 3-1/2" (slotted) 9.3 J-55 BTC 2.992" 10,680' 12,045' N/A TUBING DETAIL 2-7/8" 6.5 L-80 and EUE 2.441" Surf 5,639' 2-3/8" 4.7 L-80 8rd EUE 1.995" 5,639' 7,903' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item Zone 38' 38' Top (TVD) Btm (TVD) Hanger CIW-DCB-FBB, 11'x3 %" EUE lift & susp w/3" Type "H" BPV profile 1 341' 341' 2.313 4.650 SCSSV- Halliburton TRSV NE 5,642' 1,889' 1,842' 2.441 4.750 GLM#1-2-7/8"Weatherford SFO -1 2 3,509 3,321' 2.441 4.750 GLM#2-2-7/8"Weatherford SFO -1 B 4,800' 4,462' 2.441 4.750 GLM#3-2-7/8"Weatherford SFO -1 3 5,639' 5,195' 1.995 3.668 X -Over to 2-3/8" 6,221' 5,774' 5,316' 1.995 3.500 GUM #4-2-3/8'BST Lift Systems,GLMAT-1HP Slim hole, T-1 Latch 6,857' 6,449' 5,926' 1.995 3.500 GLM #5-2-3/8" BST Lift Systems, GLMAT-1HP Slim hole, T-1 Latch 4 7,085' 6,510' 1.995 3.500 GLM #6-2-3/8" BST Lift Systems, GLMAT-lHP Slim hole, T-1 Latch 7,731' 7,116' 1.995 3.500 GLM #7 (Orifice) -2-3/8" BST Lift Systems, GLMAT-11-11? Slim hole, T-1 Latch 5 7,778' 7,160' 1.995 3.500 Chemical Injection Mandrel 6 7,827' 7,206' 1.929 4.070 Packer- MFH 15-18# Hydraulic Retrievable w/ 30k Ib shear release 7 7,872' 7,246' 1.875 3.063 X Nipple 8 7,903' 7,273' 1.995 3.063 WLEG 9 10,226' 8,815' Open HK2 CIBP 10 ±10,236' ±8,821' 198' 11/09/18 CIBP (partially set CIBP) Updated By: JLL 11/21/18 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status A-1 6,084' 6,136' 5,595' 5,642' 52' Isolated B 6,574' 6,638' 6,040' 6,098' 64' Isolated B 6,659' 6,677' 6,117' 6,134' 18' Isolated B 6,746' 6,772' 6,197' 6,221' 26' Isolated C 6,845' 6,857' 6,288' 6,299' 12' Isolated C 6,870' 6,881' 6,311' 6,321' 11' Isolated C 7,157' 1 7,230' 6,577' 1 6,645' 1 73' 1 Isolated C 7,251' 7,289' 6,665' 6,701' 38' Isolated HK2 8,715' 8,733' 7,858' 7,870' 18' 11/09/18 Open HK2 8,750' 8,795' 7,882' 7,912' 45' 11/09/18 Open HK2 8,820' 9,018' 7,928' 8,061' 198' 11/09/18 Open HK2 9,038' 9,312' 8,074' 8,251' 274' 11/09/18 Open HK3 9,367' 9,480' 8,285' 8,354' 113' 11/09/18 Open HK3 9,497' 9,790' 8,364' 8,545' 293' 11/09/18 Open HK3 9,824' 10,015'8,566' 8,682' 191' 11/09/18 Open HK -3 West (Repeat) 10,530' 10,666' 9,029' 9,134' 136' 11/03/18 Isolated Slotted Liner: HK -3 to HK -1 West (Repeat) 10,743' 12,045' 9,192' 10,041' 1,302' 11/03/18 Isolated Updated By: JLL 11/21/18 NHilcorp Alaska, LLC Hilcrorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MGS A41A-11RD2 CT/ Rig 404 50-733-20179-03 195-119 1 10/8/2018 1 11/13/2018 Daily Operations: 10/08/18 - Monday Held ops and PJSM w/ SLB crew and crane operator. Moved misc equipment from NW deck to make room for tool shack, choke manifold, and inj w/ carrier. Spotted tool shack, choke manifold and inj w/ carrier on NW deck. Bolted up 3 1/8" 5M x 4 1/16" 10M DSA on tree- N/U risor and CT BOP assy. Hooked on to CF reel and spun it 180 degrees to face A41A-11RD2 well- did same with ops cab. Finished running all lines. Ran 11/2" CT thru injector head. Secured equipment for night. SDFN. Held operations and PJSM w/ SLB, crane and production crews. 10/09/18-Tuesday Fired up SLB CT equipment- P/U inj head and added 10' lubricator jt- installed connector and M/U to BOP stub. Tested all SLB CT BOPE to 250 psi low 4000 psi high as per Sundry. Witness waived by Jim Regg 10/6/1810:37 AM by email. B/O injector and cutoff 5' of coil- M/U Weatherford Run #1 (1.98" 3- bladed junk mill, 111/16" ECTD motor, 1.69" circ sub (3/8" ball drop), 1.69" disconnect (1/2" ball drop), 1.69" dual BPV, 1.7" dimple CTC= 14.32'). Opened well. 0 psi tb pressure, 0 psi IA pressure, 46 psi OA pressure. TIH @ 30 fpm pumping.6 bpm 1700 psi to 350' getting— 3/4 returns- very minimual solids. Shutdown pump and attempted to go dry- no go. Brought pump up again and continued in hole- lost returns at 2310'- re-established returns. Motor stalled at 2,470'- P/U and worked back w/ no issue- heavy slug of scale hit at 2600'. Hit 2nd small bridge at 5,370'- worked pipe to regain returns. Scale amounts increasing. Continued in hole to 3rd small bridge at 7,470'- momentary loss of returns then regained returns- increased pump rate slightly to .8 bpm, press now at 3000 psi. took weight briefly at 8,334' (R nipple above pkr) then fell thru- lost returns (pump psi 1300). Dropped out EOT to 8,420' (18' out)- pulled back thru 2.010" id RN nipple with no issue. Once above pkr/nip assy, POOH at 100 fpm .8 bpm- regained circ- 2200 psi. Pulled inside lubricator and closed swab valve- B/O injector and dropped out Weatherford tools- no damage or significant wear on mill- B/D tool string. B/O lub jt and set down injector head. Secured well and equipment for shutdown. —1 bbls scale recovered during C/O. SDFN. Held operations and PJSM w/ SLB, crane and production crews. 10/10/18 - Wednesday Fired up SLB CT equipment- after talking with crane op & SLB supervisor decision was made not to M/U to stub and blow down reel due to high winds (35 knot sustained N winds). Continued B/D misc equipment in preparation for CT loadout. Wind direction began changing to Easterly direction- hooked up injector, M/U lub jt and stabbed on BOP stub. Blew down coil reel w/ N2 to rig tank- allowed N2 to bled off. Pulled coil tb from inj- B/D all circ, electrical and hydraulic lines. B/O gooseneck from inj- N/D BOP & riserfrom tree- packaged equipment in shipping frames. On deck crane worked halted at 1530 hrs due to high winds (50-60 mph)-SLB CF rig down 95% complete. Stoodby during high wind. SDFN- SLB Supervisor and Weatherford tool hand departed location. Held ops and PJSM w/ SLB, crane and production crews. 10/11/18 - Thursday Finished R/D SLB CT equipment- packing up for back load. Backloaded SLB CT package- on loaded Pollard ELine equipment. Position Eline equipment on NW deck. SLB CT personnel departed- Pollard ELine personnel arrived. Pollard received orientation and filled out work permit & JSA. R/U on tree w/ full Bowen lubricator, grease head and WL rams- tested lub to 1000 psi (working thru minor leaks). M/U Run #1 ( 1.7" wt bar, 1.56" mech jar, 1.7" CCL, 1.5" cent, 1.5" anchor, 1.375" cent, 1.68" RCF, 1.68" anchor, 1.625" cent = 32'). TIH to tag at 720'- attempted to work thru but no go- pulled into lub and closed swab valve- B/O lub and checked out tool string- production opened flow line to header pressure f/ 30 mins (no rate gauge). Tool string checked good- pulled inside lub and M/U to tree. Opened well and TIH to 8,323' (WLM) with no issues- could not get deeper (R nipple at 8,335' MD). Opened flow line to choked header pressure (injecting FIW)- could not get deeper- taking 600#s overpull to get free- shut flow line. Pulled CCL strip from set down to 8,100'to determine cutting depth-tb connections undistinguishable on strip- POOH. Closed swab valve and drained lub- B/O lub and B/D Run #1- no damage to tool. M/U Run #2 (1.7" wt bar, 1.6" mech jar, 1.7" CCL= 13.8'). TIH to tag at 1705'- opened flow line to choked header press and injected- continued in hole to 3,410' and started tagging again- set in place while injecting for 30 mins then continued in hole to tag at 8,323'- unable to get deeper with/without injection. POOH, Closed swab valve- drained lub- B/0 tools- laid down lub. Stand down to rest ELine and crane crews. Called for backup CCL from Pollard. Held safety and operations meetings with crane and production personnel. UHilcorp Alaska, LLC HiWell Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MGS A41A-11RD2 CT/ Rig 404 50-733-20179-03 195-119 10/8/2018 1 11/13/2018 10/12/18 - Friday Pollard ELine crew down for rest- 2- 111/16" CCL arrived via helicopter. FIW injection started at 0630 hrs. Fired up equipment and West crane P/U Pollard lubricator- M/U Run #3 (same as #1 but w/ different CCL)- pulled inside lub- shut down injection and opened well. TIH to 2,751' and began setting down - unable to work deeper- opened flow line and began injecting. Worked to 2,910'- P/U and injected f/ 30 mins at max rate- closed flow line and worked tool to 3,003'- opened flow line again at 3/4 rate but could not make hole. Rocked pressure in efforts to break thru obstruction- pressure is not bleeding off as quickly as before- bled down 1300 psi in 30 min (injection has changed). Discussed situation with Ops Eng and decision was made to pull ELine and R/U Stine. Lined up SL equipment from Pollard and crew from Anna- arranging transportation for both. IA pressure 2500 psi. POOH w/ Run #3- R/D ELine- Standby for SLine. Turned West crane over to Udelhoven crew dismantling welding shop. Offloaded crane operator, Pollard Stine crew from Anna and SLine equipment from beach (plus groceries). Go over details of job w/ Pollard crew. Spotted unit, strung line and M/U lubricator- M/U Run #1 (10' of 1 1/2" stem, knuckle, oil & spang jars, 3' 11/2" stem, 1.75" x 7' DDB w/ flapper)- M/U to well. Opened swab (1700 psi IA)- TIH to tag at 2,983' (SLM)- worked/bailed to 3,119'- sticky, having to spa ng free. POOH to check bailer. Pulled in lub and closed swab- B/O lub and B/O flapper from end of bailer. Bailer full, — 1/4 gallon of scale/sludge (pic in 'O'drive)- M/U 2" bailer and pulled inside lub- M/U to well. Opened swab and tagged inside tree- could not get thru- pulled inside lub and closed swab- R/U air to blow sludge prior to B/O lub- unplugged bled line. B/O lub and B/O 2" bailer- M/U 1.75" bailer. Pulled inside lub and M/U to well. Opened well and TIH w/ Run #2 to tag at 1,216' -worked bailer to 1,722'- POOH into lub- closed swab- B/O lub and emptied full bailer. M/U flapper- pulled inside lub and M/U to well. Opened well and TIH w/ Run #3 to 1,200' -worked tool to 1,387'. POOH recovering full bailer of scale & sludge- B/O 13/4" bailer M/U 1.65" gauge on tool string- pulled inside lub and M/U to well. Opened well and TIH w/ Run #4 to tag at 1,382'- worked tool to 1,722'. While attempting to get deeper, tool would hang at 1,695'- worked tool from 1,722'to 1,695'. Took 15 mins to work tool free. POOH- closed swab and B/0 lub. Attempted to inject into well but it pressured up tb and IA. Bled off pressure on both- B/O gauge M/U 13/4" bailer and additional 5' stem- pulled inside lub and M/U to well. Opened well and TIH w/ Run #5 to tag at 1,562'- worked tools to 1,692'- POOH- closed swab- B/O lub- B/O bailer bottom -full recovery of scale and sludge. M/U bailer flapper and pulled inside lub- M/U towel]. Opened well and TIH w/ Run #6 to tag at 1,701' -worked tools to 1,795- POOH- closed swab- B/O lub- B/O bailer bottom- full recovery of scale and sludge. M/U bailer flapper and pulled inside lub- M/U to well. Opened well and TIH w/ Run #7 to tag at 1,531'- worked tools to 1,811'- now having to beat up to get free- POOH- closed swab- B/O lub- B/O bailer bottom- full recovery of scale and sludge. M/U bailer flapper and pulled inside lub- M/U to well. Opened well and TIH w/ Run #8 to tag at 1,811' worked tools to 1,827'- POOH- closed swab- B/O lub- B/O bailer bottom -full recovery of scale and sludge. Laid down lub and secured well. SLine crew and night crane op will rest then resume work at 1800 hrs to allow Udelhoven access to West crane during the day. Held operations meeting with day crane crew, Udelhoven and production crew. BHilcorp Alaska, LLC Hikrorp Alanka,il.f Well Operations Summary Well Name Rig API Number Well Permit Number Start Date I End Date MGS A41A-11RD2 CT/ Rig 404 50-733-20179-03 195-119 10/8/2018 1 11/13/2018 10/13/186-Saturday Construction and crane crews continued demobing welding shop- moving all equipment to mud boxes, baskets or storing on platform. Moved both sections into position to be offloaded in the morning. Raised crane and P/U S/L lubricator- M/U Run #9 (15' of 11/2" stem, knuckle, oil & spang jars, 3' 1 1/2" stem, 1.75" x 7' DDB w/ flapper)- pulled inside lub and M/U to well. 0 psi tb, 0 psi IA, 0 psi OA: Opened well and TIH w/ Run #9 to tag at 1,755'- worked tool 10 mins and fell thru to 1,895'- unable to get deeper. POOH into lub- closed swab- B/0 lub- B/0 bailer btm- full recovery of scale & sludge. B/O bailer M/U 2" scratcher- pulled inside lub- M/U to well. Opened swab valve and TIH w/ Run #10 to 1,902'- worked from 1,902' to 1,550' several times- then worked to 2,065'- unable to work deeper- POOH into lub- closed swab- B/O lub- broke off scratcher- M/U 1.75" bailer- pulled into lub- M/U to well. Opened well and TIH w/ Run #11 to 1,959'- worked tool to 1,995'- unable to work deeper- tool stuck at 1,990'- 15 jars hit at 1400#s and tool came free- POOH into lub- closed swab- B/0 lub- B/O bailer btm- full recovery of scale & sludge. Laid down tool string, cut wire and reheaded line. M/U 11/2" bailer on tool string- pulled inside lub and M/U to well. Opened well and TIH w/ Run #12 to tag at 2,002'- worked tool to 2,030'- unable to get deeper- POOH into lub- closed swab and B/O lub- B/O bailer btm- full recovery of scale & sludge. M/U btm and pulled inside lub- M/U to well. Opened well and TIH w/ Run #13 to tag at 2,032'- worked tool to 2,034'- unable to get deeper- POOH into lub- closed swab and B/O lub- B/O bailer btm- full recovery of scale & sludge. M/U btm and pulled inside lub- M/U to well. Opened well and TIH w/ Run #14 to tag at 2,032'- worked tool to 2,046'- unable to get deeper- POOH into lub- closed swab and B/O lub- B/O bailer btm-full recovery of scale & sludge. B/0 bailer M/U 2" scratcher- pulled inside lub- M/U to well. Opened well and TIH w/ Run #15 to tag at 2,057'- worked tool to 2,082'- unable to get deeper- POOH into lub- closed swab and B/O lub- B/O scratcher M/U 11/2" bailer. Pulled inside lub- M/U to well. Opened well and TIH w/ Run #16 to tag at 2,078'- worked tool to 2,080'- unable to get deeper- POOH into lub- closed swab and B/0 lub- B/O bailer btm- full recovery of scale & sludge. M/U bailer btm and pulled inside lub- M/U to well. Opened well and TIH w/ Run #17 to tag at 2,078'- worked tool to 2,081'- unable to get deeper- POOH into lub- closed swab and B/0 lub- B/0 bailer btm- recovery of scale & sludge. M/U bailer btm and pulled inside lub- M/U to well. Opened well and TIH w/ Run #18 to tag at 2,081'- worked tool to 2,082'- unable to get deeper- POOH into lub- closed swab and B/O lub- B/O bailer btm- recovery of scale & sludge. M/U bailer btm and pulled inside lub- M/U to well. Opened well and TIH w/ Run #19 to tag at 2,082'- worked tool to 2,083'- unable to get deeper- POOH into lub- closed swab and B/O lub- B/0 bailer btm- recovery of scale & sludge. M/U bailer btm and pulled inside lub- M/U to well. Opened well and TIH w/ Run #20 to tag at 2,083'- worked tool to 2,084'- unable to get deeper- POOH into lub- closed swab and B/O lub- B/O bailer btm- recovery of scale & sludge. M/U bailer btm and pulled inside lub- M/U to well. Opened well and TIH w/ Run #21 to tag at 2,084'- worked tool to 2,086'- unable to get deeper- POOH into lub- closed swab and B/0 lub- B/0 bailer btm- recovery of scale & sludge. M/U bailer btm and pulled inside lub- M/U to well. Opened well and TIH w/ Run #22 to tag at 2,086'- worked tool to 2,087'- unable to get deeper- POOH into lub- closed swab and B/0 lub- B/0 bailer btm- recovery of scale & sludge. Laid down lubricator and secured well- shut down to rest SL crew. Held safety meeting w/ construction, slickline, crane and production crews. 10/14/18-Sunday Offloaded 2- halves of platform A welding shop onto M/V Resolution to be offloaded on Dillion platform. Continued cleaning and organizing deck in preparation to setup HAK 404. 1400 hrs onloaded support beam package for rig. Continued cleaning and organizing. Generated work permits and held P1SM w/ Pollard SL and EL crews w/ crane op. Raised crane and P/U S/L lubricator. 0 psi tb, 0 psi IA, 0 psi OA,M/U Run #23 (15' of 11/2" stem, knuckle, oil & spangjars, 3'11/2" stem, 1.875" gauge ring)- pulled inside lub and M/U to well. Opened well and TIH to tag at 1,590'- POOH into lub- closed swab valve and B/O lub- B/0 1.875" gauge- M/U 1.75" gauge on tool string- pulled inside lub and M/U to well. Opened valve and TIH w/ Run #24 to tag at 2,087'- POOH into lub- closed valve and B/O lub- R/D slickline. R/U Pollard Eline unit w/ full lubricator- P/U lub w/ crane- M/U tool string (1.7" wt bar, 1.56" mech jar, 1.7" CCL, 1.5" cent, 1.5" anchor, 1.375" cent, 1.68" RCT, 1.68" anchor, 1.625" cent = 32'). M/U to well and opened swab. TIH to tag at 2,060'- P/U logging tb collars- fired cutter in mid jt at 2,011'. POOH- R/D ELine. SDFN, Held operations and PJSM w/ construction, crane and production crews. KHilcorp Alaska, LLC HiWell Operations Summary Well Name Rig API Number Well Permit Number Start Date I End Date MGS A41A-11RD2 CT/ Rig 404 50-733-20179-03 1 195-119 10/8/2018 1 11/13/2018 10/15/18 - Monday Continued cleaning and organizing W side deck in preparation to set 404 support beam package in place. Backloaded Pollard EL & SL equipment onto M/V Titan. AA crews and WSM onboard- received orientation and room assignments- generated work permits and began moving Edelen support beam package in place for 404. Lowered shorter section to deck- crane op determined that boat was needed in order to get longer section into position on West deck- M/Vs down due to wind and waves- standby for winds to lay. Night crane op onboard- discussed plan to skid beam across deck using both cranes in order to position load to be picked with West crane- moved forward support beam in place- attached rear section then positioned stabilizer beams- set base beam in place 48" from well center- cut and rewelded front cross beam to support beam. Shutdown construction crew for rest- rig crew began cleaning CT sludge and scale from rig tank while waiting on 1st load of 404 package. Held operations and PT safety meeting w/ construction, crane, rig and production crews. 10/16/18 -Tuesday Cont. install base beam & clean pits. Unload boat, install rig mat to base beam, set carrier, install "A" leg, install DW, couple drive shaft, pin derrick. Installed driller side walkways- secured carrier to support beams- repositioned vac unit inside support beams- rearranged supply and tool connexs to make room for mud pump and tank. Worked M/V Resolution onloading 2nd load of W/O equipment: receiving change conex, driller's shack, rig floor, driller's shack stairs, bang box, off driller's side walk ways, koomey hoses, misc stair ways, koomey unit, test pump, 2- tong power packs, 2 -jet heaters, and choke house. Mounted off driller's side walkways- greased all crown sheaves. Moved rig tank, koomey unit, choke house and driller's shake into position- moved supply conex to pipe rack to make room for mud pump. 10/17/18- Wednesday Removed drill line spool from derrick- assisted crane op with positioning equipment on decks, moving change room and parts conex- prepped derrick to be raised- continued housekeeping and organizing around platform, waiting arrival of next load of W/O equipment. Began prepping for platform rig skid East, clearing path and reading electrical lines, moving drill line spool and walkways, rigging lights in cellar. Worked Reso receiving Total Safety & Quadco mud boxes, flat iron f/ ladder cage, double gate, annular, stripping spool, basket w/ subs and other misc items (manifest #06). NOS arrived 2000 hrs- void tested hanger to 5K. Worked M/V Titan receiving assorted stairs and landings and basket with hoses. Greased choke house valves, NOS attempted to set BPV, Unable to pass BPV thru flow master valve -scaled up. Placed jacks to skid rig and stood by until Reso could pull into position to backload items in path of skid. Took spang jars and 2.60 gauge and cut thru top half of master valve then gauge fell to profile. NOS rinsed profile and set BPV- good set- B/O BPV and examined same- reset BPV. Backload Reso with transfers to'C' and items going to OSK. Removed hand rails in skid path. Held tour change P1SM with all personnel. Continued prepping to skid platform rig. 10/18/18 -Thursday P1SM, skid platform rig 16' east to open up deck space for Eq. secure & safe out same. N/D tree, clean & check lift threads, install blanking sub, N/U adaptor DSA, spacer spool, riser mud cross and valves, wk on arranging drill deck for pits & pump, cont. working in modifying stairs & landing for west side of carrier. Repositioned rig tank and spotted mud pump. Continued N/U BOPE (double gate and annular). Redirected 8" suction fittings 180 degrees on rig tank and pump. M/V Titan delivered choke and kill coflex lines from Monopod. Laid out koomey hoses and plumbed mud pump to tank. Welder finished stairs to walkway on off driller's side of rig. Repositioned koomey unit. N/U stripping head. Connected koomey hoses to unit, installed fittings to BOPE and connected hoses- checked precharge on koomey bottles -0300 hrs shut crane work down due to winds -filled out confined space permits and began cleaning solids out of rig tank from CT jobs. UHilcorp Alaska, LLC Hilcorp Alusku, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MGS A41A-11RD2 CT/ Rig 404 50-733-20179-03 195-119 10/8/2018 1 11/13/2018 10/19/18 - Friday Continued N/U ops: crane operator swung coflex hoses down- attached choke & kill lines off mud gate- continued cleaning rig tank traps with vac system- filled in handrails after rig move- hooked up air to koomey unit and remote panel- pressured up koomey and function tested BOPS- continued housekeeping and organizing deck and connexs. r/u total safety gas system, Quadco install PVT system, Wind limiting some activities. Covered JSA on derrick raising and raised derrick (half mast)- covered crane man-lift operations JSA and check all lines in derrick. Secured guy lines- spooled drill line on draw works. 2200 hrs worked M/V Titan receiving 2- baskets of WFTs, 3- sets of tb tongs, pup jts, test jts, x-over basket and heater trunks. Installed vent tube on gas buster. Scoped up derrick and secured all guy lines- used crane w/ man-basket and flagged guy lines. Ran line from choke manifold to gas buster- began running pump and supply lines. 10/20/18-Saturday Install rig floor & wind walls, (repair pockets as needed) install stairs to ODS & DS of floor, install beaver slide, c/o companion flange on standpipe for kill line, install kill line, R/U HP mud line to standpipe manifold, R/U & skid heliport to the east away from derrick for better helicopter egress, secure same. Slipped drill line on drum- connected FIW supply line to pump & tank- plumbed test pump as needed- emptied waste drum into cutting box- moved test jt around to beaver slide. 2015 hrs offloaded M/V Titan w/ bundle of hoses from Steelhead- decision made not to backload due to winds gusting 40 mph. Loaded rig floor with handling tools and tongs. Ran hose from stripping head to rig tank- moved set of steps to rig tank. M/U a 2 7/8" test jt w/ RHR sub on btm- pumpin, SV x 2, IBOP on top- place fire extinguishers around rig as needed. 10/21/18-Sunday Changed out defective 2" FIW supply hose due to leaking- Filled system w/ FIW using mud pump-functioned all pump controls. Closed annular and attempted shell test- worked thru numerous leaks (determined that Sweeney wrench was not working correctly- repaired wrench). Performed successful 2500 psi shell test- continued organizing around W/O package. Jeff Jones/ AOGCC witness onboard at 1900 hrs. Began BOPE test- tested all BOPE 250 psi low 2500 psi high as per Sundry in accordance with Hilcorp and AOGCC requirements using a 2 7/8" test joint. Performed a successful koomey draw down test. One FP target T installed incorrectly, 2245 hrs state witness departed. Target T corrected and retested good, B/D test equipment- prepped floor to POOH- installed shaker screens- welder modified beaver slide to fit current setup. Cont work on punch list items. R/U Gill tongs w/ stiff arm- changed out bowl and slips for air slips- redressed air slips to 2 7/8". P/U test it to retrieve blanking sub. 10/22/18- Monday M/U landing jt, Pull blanking sub, pull BPV install landing it, BO LD pins, pull hanger free @ 45k, cont. pull t/55k & work, w/no headway, r/u & break circ. 1.5BPM, 25psi. Housekeeping & working on r/u list while waiting on boat with a-line eq. 1530 hrs brought Pollard ELine on board- pulled 45k and set on slips- R/U ELine w/ 13/4" chemical cutter and TIH tagging at 2,061'- P/U to 2,016' and made cut- POOH and R/D ELine. Pulled hanger to surface and worked same- prepped to POOH. Reworked stiff arm on tongs. Pulled 5- singles wet (using collar clamp)- lined up and pumped 1/2 bbl- pressured up finding 2 leaks- repaired leaks and pressured up to 1500 psi LW- bled off pressure- continued POOH wet. Bottom of it #23 and top of jt #24 plugged- drained fluid from #23 before flying to pipe rack, pulled 34 its total. 10/23/18-Tuesday Cont. POOH wet t/ EOT. L/D 72 full joints & one cut it 15.35'2 7/8" tubing, 1963' total. Clean & clear floor. Prep handling tools for P/U BHA & p/u 2 7/8" PH6 wk string. Install drain on beaver slide. P/U BHA, 5 3/4" overshot, 4 3/4 bumper sub, xo =16.46', working issues to get hyd pressures up to get proper tq. TIH w/ Weatherford BHA#1 picking up PH-6 workstring strapping, drifting and torqueing to 4000 FPT. 13 jts in hole at tour change =415'. Continued in hole w/ BHA #1 to 1,972' (64 jts). Changed out elevators and P/U power swivel- tested 3 1/2" IF Kelly valves to 250 psi low 2500 psi high as per Sundry. Attached snub lines- M/U valve w/ 2 7/8" PH-6 x-over sub to swivel saver sub- r/u power swivel. Hilcorp Alaska, LLC HJlwrp Naeka, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MGS A41A-11RD2 CT/ Rig 404 50-733-20179-03 195-119 10/8/2018 1 11/13/2018 10/24/18 - Wednesday Cont. r/u swivel, p/u 2 pup joints & single tih t/ 1988',CBU rev x2, @4 BPM, 550 psi. Get parameter's, up/dn /rot wt 24k, rot 30rpm tq - rih t/tag top of tubing @ 2014', cont set down 10k. P/u Sk op, verify overshot engaged set back down, p/u t/75k, put 2500 tq in string, slack off slow t/50k, tq fell off, p/u worked 2500 tq in & came down t/50k tq fell off again & free rotate @ 500. P/u t/1988' up wt 64k. L/D joint, swivel, c/o handling eq. POOH I/d 2- pup joints & stand back wk string (64 jts 2 7/8" PH6 ), L/D BHA. Cont. POOH L/D 2 7/8" completion tubing- 22 jts laid down. Continued POOH- decision made to R/U different mud bucket for better containment (18 its pulled = 40 total new fish OOH). Changed out rubbers in mud bucket and R/U same. Continued pulling pipe- laying down singles- 74 jts of new fish laid down +73 its from 1st fish = 147 of 304 its prod string OOH. Worked M/V Titan receiving empty pipe rack- unable to back loaded pipe rack with 146 jts recovered prod tb due to weight indicator issue and no back deck space on boat- adjusted brakes and greased rig while prod mech assisted with mud pump voltage issue. Continued pulling pipe- laying down singles. Total of -89 joints I/d. 10/25/18 - Thursday Continued POOH, laying down recovered 2 7/8" production string. Serviced draw works, block, tongs and rig. Finished POOH to broken/twisted off 'K' anchor (recovered'K' anchor measures .55') (full tb recovery of production string). Cleared and cleaned rig floor and deck. M/U WFT BHA #2 (4 1/8" pkr mill w/ 2" x 1.40' pilot mill, DP sub, DB sub, 3 1/8" x 11/4" B & O jars, DP sub, 2- 3 5/8" boot baskets, DB sub, 6- 3 1/8" x 11/4" spiral DCs, XO sub, 3 1/8" x 11/4" Acc jar, XO sub = 222.52'). TIH w/ BHA #2 running 32 stands 2 7/8" P-110 PH-6 workstring to 2,177'. Continued in hole w/ BHA #2 picking up 2 7/8" P 110 PH-6 workstring t/3691', strapping, drifting and torqueing to 4000 FPT, up/dn wt 33k. 10/26/18- Friday Continued P/U 2 7/8" P-110 PH-6 workstring, RIH from 3,691' to 5,971' for a total of 189 its in hole. Serviced rig. Continued P/U workstring, RIH from 5,971' to 8,317'(266 its in hole) (PUW 66k SOW 47k). Worked M/V Titan receiving misc iron, hose, heater trunks, tongs, pressure washer. P/U 4267 and tagged 7' in = 8,326'(w/ +2' elev correction)- laid out single and P/U swivel. Tested Kelly hose to 1000 psi- M/U #267 on swivel and installed stripping element, ran in lockdowns- set power swivel torque to 2500 FPs. Began pumping at 1.5 bpm 117 psi (initial pressure- returns at shaker)- shutdown to work leak at btm of stripping spool and troubleshoot stroke counter. Began pumping again and stripping element leaked- B/O L/Ds and pulled element- B/D stripping head and replaced square'o'ring and rubber- reinstalled stripping element and ran in L/Ds. Began pumping/circulating at 2 bpm 600 psi (LW), PUW 66k, SOW 53k, RotW 581k, 65 RPMs at 1800 FPT- eased down and tagged at 7' in = 8,326' (2' of elev correction added). Begin milling on packer. 10/27/18 -Saturday Cont. Milling 5" SABL packer @2 bpm 600 psi, PUW 66k, SOW 53k, RotW 58k, 65 RPMs at 1800 tq, f/8328't/8330', tq dropped off & started pushing packer down hole 8', CBU, shut down pumps, monitored well, went down & tagged packer checking for fill, tagged at previous depth clean. R/D swivel & stripping head. POOH w/ BHA #2 pumping displacement every 10 stands. B/D BHA-Mill had approx. 50% wear, boot baskets full of shavings. Clear & clean rig floor. M/U 2 7/8" test it w/ test plug and blanked & ported sub on btm- pumpin, 2- SVs & IBOP on top. Attempted to land test plug but it stopped - 6" high- stack would not fill- pulled test plug and cut off'e'rings and attempted to land again- nogo. B/O test plug and M/U hanger (that was pulled from well) on test it- attempted to land with no success- R/U chain horses and attempted to pull into position- nogo. Pulled test jt and observed scarring ring" 1/2" up around btm of hanger. B/O hanger and M/U test plug- lowered to hanger and attempted to pull into position with chain horses- nogo- pull test plug and observed same scarring at btm of test plug. R/U and flushed tb head with rig pump (using test jt opened ended)- M/U test plug and attempted to land testjt- nogo- L/O testit. M/U WFT BHA #3- spear, bumper sub, oil jar, double pin sub, bit sub, 6-3 1/8" DC, xo sub, slingerjar, xo sub to 2 7/8" PH6 wk string = 216.45 (will rih to liner top for weight & set plug to test BOPE). 10/28/18-Sunday C/O handling tools, rih w/BHA #3 on stands of 2 7/8" PH6 wk string t/5753'. C/O handling tools p/u 7" test packer& m/u connections. RIH t/6110' up wt 47k, do wt 38k, set packer @355'. R/U & test BOPE as per Hilcorp & AOGCC requirements. Witness waived by Jim Regg on 10-27 @ 4:19 pm, test w/ 2 7/8" tj 250 low, 2500 high. Worked thou downhole leak issues to complete test. Continued w/ BOPE test- pulled pkr and changed out test jt to 2 3/8", adding safety valve in string in order to B/O and test blinds- worked thru downhole leaking issues to complete test. Pulled leaking PH6 valve. Pulled storm pkr- presently setting up packer/ test jt assy to rih, set totestblinds. HHilcorp Alaska, LLC HiWell Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MGS A41A-11RD2 CT/ Rig 404 50-733-20179-03 195-119 1 10/8/2018 1 11/13/2018 10/29/18 - Monday Installed Kelly valve on top of storm pkr- swap out tongs. RIH from 5,753' to 6,040'(5 stands on top of pkr)- set pkr- B/O single. Tested blinds & CM #10- 250/2500. Perform koomey draw down test. Screwed back into string & pulled pkrto surface- assisted Tripoint in B/D pkr. Serviced rig. Installed slow- decent device in derrick. TIH from 5,753' to 8,338'. Speared into burnt over pkr and jarred same free (hittingjars 25k over) hit 8x started moving up hole, drug it 65'- with op of 10-15k, tailing off then smoothed out,POOH w/ fish from 8,338'to 4,689' (60 stands). Continued POOH after tour change- pulled to BHA (133 stands in derrick). B/D BHA- no fish- grapple in release position. Installed new grapple (2.430" nominal catch) and M/U BHA #4 (same as #3- Itco spear w/jars & collars). TIH w/ BHA #4 on 2 7/8" 7.9# P-110 PH-6 workstring to 3433'. 10/30/18-Tuesday Cont. tih f/3433' t/ 8280' up wt 61k, do wt 46k, tagged fish and chased to 8338'. Engage fish, p/u t/ 80k and started dragging up hole t/8268' & came free, chased back t/8338' engaged pulled with same result. Rih engaged pulled t/8125'& lost fish, tripped back to 8338' made attempts engaging fish but appear to be coming free with 3-6k op. POOH f/ 8,338' to 2,594' (95 stands OOH). Tour change out- continued POOH (39 stands) to BHA #4. B/D BHA- recovered remainder of fish = 55.17') milled over pkr measured 2.40'). M/U WFT BHA #5 (4 1/8" Piranha Mill, 2- 3 5/8" x 3/4" boot baskets, 3 1/2" x 1" casing scraper, 3 1/8" x 1" bit sub, 3 1/8" x 11/4" B&O jars, 3 1/8" x 11/4" X-over sub, 6- 3 1/8" x 11/4" DCs, 3 1/8" x 11/2" X-over sub, 3 1/8" x 11/4" Acc jar, 3 1/8" x 1 1/16" WS X-over sub = 224.00'). TIH w/ BHA #5 t/6857', on 2 7/8" 7.9# P-110 PH-6 workstring torqueing every connection to 4400 FPT. 10/31/18 -Wednesday Cont. TIH t/8318', up wt 61k, do wt 46k. P/U & rig up power swivel, p/u single & install stripper head- M/U to string and installed stripping element into head- secured same. UP wt 63k do wt 48k RotW 54k- wash/reamed f/ 8,338' to 8,654' (taking 1 to 5 jt bites) at 2.5 bpm 800-1000 psi LW then circ hole clean SW 2.7 bpm 1050 psi (after each bite). At tour change: off btm 1/2 jt circulating hole clean (SW) 2.75 bpm 1050 psi- 4400 stks circ. Eased down (SOW 50k PUW 66k) to 8,654' and M/U single in string- attempted to break circ LW but pressured up. Laid out single and P/U off btm 1/2 it- broke circ SW and washed/rotated down to 8,654'. Circulated tb volume+. M/U singles washing /rotating from 8,654'to 8,744' at 2.3 bpm 760 psi LW. P/U 1/2 jt off btm and attempted to rev hole clean but pressured up- attempted to break circ LW but pressured up- attempted SW again-tried working pipe and surging pressures but failed to break circ. Pulled/ laid out 2-jts. R/U to bypass swivel and standpipe manifold- pressured up LW to 2500 psi but could not clear tb. Plumbed standpipe manifold back in- R/D swivel. POOH w/ BHA #5 wet from 8,684' to 6246'. 11/01/18 - Thursday Cont. POOH, t/ BHA #5, found fill first stand of collars. Cleaned out solids in BHA, recovered 2 boot baskets full of metal pieces & scale, throat of mill was packed off with metal & scale as well. Clean & clear floor & drill deck from cleaning out BHA, c/o Kelly hose, service rig. P/U BHA #6 (4 1/8" Varel Slipstream bit (jets pulled & 3/4" hole drilled in center), 3 1/2" x 1" casing scraper, 3 1/8" x 1" bit sub, 3 1/8" x 11/4" B&O jars, 3 1/8" x 11/4" X-over sub, 6 3 1/8" x 11/4" DCs, 3 1/8" x 11/2" X-over sub, 3 1/8" x 11/4" Acc jar, 3 1/8" x 11/16" WS X-over sub = 214.96'). TIH w/ BHA- ran in one stand and broke circ LW & SW- looks good. TIH to 8,675'(139 stands+ BHA in hole). P/U power swivel- M/U single #279 and install stripping element- M/U to string- land element in head. Break circ LW briefly then switch around to SW at 2 bpm 700 psi. Wash down to 8,735' reversing tb clean. Continued down to 8,744' and began having slight plugging issues- turned fluid around LW and continued circ- depth at report time is 8,744'. 11/02/18 - Friday Wash & ream f/8,744' t/9,404', circ LW 3.75 bpm 1800 psi- (CBU every 5 its) PUW 64k SOW 54k, RotW 55k, 70 RPMs, tq 2200. Continued washing/rotating from 9,404'to 9,648'. Changed out stripping rubber. Continued wash & ream from 9,648' to 9831'. 11/03/18-Saturday Wash & ream f/ 9,831't/ 10,256' circ 3.8 bpm 1920 psi- (CBU every 5 jts) up wt 76k, do wt 52k, rot 70 RPM, 2200 tq, rot wt 59k,CBU clean, r/d swivel & stripping head,Pooh, up wt 74k, do wt 51k to top of liner at 5,654'- reversed hole volume plus- returns clean. POOH from 5,654'to 1,561' standing back 142 stands (filled hole every 10 stands). Finished POOH to BHA- laying down 46 singles. B/D WFT BHA #6 (including collars). R/U Pollard Eline- TIH w/ Run #11-11/16" Gamma Gun, #10 setting tool, 3.71" bridge plug to 10,236'- logged into position and set BP at 10,226'. POOH. Hilcorp Alaska, LLC Hilcorp Almska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MGS A41A-11RD2 CT/ Rig 404 50-733-20179-03 195-119 10/8/2018 1 11/13/2018 11/04/18 -Sunday POOH w/ a -line, found mandrel/setting tool to have separated incorrectly for possible partial set on CIBP. R/U & test CIBP/casing t/2500, pressure up t/ 2500, pressure fell off 500 psi in 5 min, check surface lines & eq, pressure back up with similar results. Work on prepping floor for removal, drain pits & prep to clean, prep for tubing spool change while waiting for CIBP & running tool to set a second. Receive CIBP & running tools, r/u & surface test, had bad firing head, c/o tested good. RIH w/3.92" CIBP, t/10231', pull up into position @ 10226', set BP, adjust ELU, POOH. Filled hole and pressure tested to 2500 - lost 250#s in 5 mins- bled off pressure- R/D ELine. Prepped rig floor to RIH w/ workstring. TIH w/ 50 stands of 2 7/8" 7.9# P-110 PH -6 workstring to 3,034'. M/U Tripoint Storm pkr w/ valve into string and TIH (4 stands)- setting pkr @ 240' EOT @ 3,287'. Pressured up annulus to 2500 psi and held on chart f/ 35 mins- good test. Released pressure and B/0 from valve above storm pkr, closing valve. POOH racking back 4 stands of workstring. Cleared floor of tools & tongs- pulled center section and N/D stripping spool- dismounted floor. Removed studs from annular and installed bolts to secure lifting device. 11/05/18 - Monday Finish r/u & lift stack, c/o tubing spool t/13 5/8 3M x 11" 5M CIW-DCB, test void 250/300015 min each good, reinstall floor & hookup accumulator, choke/kill lines, function test BOPE good. M/U 2 7/8" test it., r/u t/test BOPE, fill surface eq. shell test good. Test BOPE as per Hilcorp & AOGCC requirements. Witness was waived by Jim Regg @ 11:40 on 11-5-18, test 250 low, 2500 high w/ 2 3/8" & 2 7/8" T.I. Worked thru 3 FPs, 1- annular sealing on 2 3/8", 2- CMV #2, 3- grease Cl. Pulled test plug and B/D test equipment. M/U Tripoint releasing sub and TIH to 240'- engage storm pkr, released same - pulled out to pkr and laid it done. POOH w/ 40 of 50 stands of 2 7/8" PH -6 workstring at report time = 606'. 11/06/18 -Tuesday Continued POOH from 606'to EOT. Reinstalled wind walls on rig floor. M/U Tripoint test pkrf/ 5" casing and TIH entering liner top @ 5,654' (SM). Worked thru tight spots at 5,688', 5,729', 5,768'- unable to work past 5,810'- decision made to POOH. POOH and checked condition of 5"test tool- nothing damaged on tool, still in RIH position, no markings on tool. Crew cleared and cleaned floor while conferring with Eng. M/U singlejt of 2 3/8" on btm of 5" Tripoint test tool (BHA =46.51'). TIH to 5,642' and installed stripping element- eased down and tagged TOL (5,654')- rotated string 1/2 rnd to left and slacked off to 5,673' (EOT)- packer at 5,641'. Lined up and circ LW at 3 bpm 1050 psi f/ 500 strokes (working pipe w/o coming out of liner)- turned fluid around and rev'd 1200 strokes at 2 bpm 200 psi. B/O hose- PUW 42k SOW 37k- continued in tagging at 5,688'w/ pkr (EOT at 5,719')- had to drop 10k down to push on past tight spot. Set pkr at 5,734' w/ 1 rnd RHT. Pressured up annulus to 1500 psi and held f/ 5 mins- R/U chart recorder and pressured up to 2500 psi- held solid 30 min test (battery died at 12 mins). Released press and pressured down tb to 1500#s on gauge- lost 500#s in 7 mins- released press. Attempted to RIH but had same tight spots as previous run (@ 5,729' and 5,768'- made 3 attempts to get past but nogo). POOH w/ test pkr. t/4457'. 11/07/18- Wednesday Cont. POOH f/4457'with 5" test packer. Tong heads cammed over & locked on tubing, break connection & I/d tongs. P/u spare tongs & r/u. Cont. POOH I/d 5" test packer. Housekeeping & rig maint. while waiting for boat to deliver rest of BHA. Began M/U WFT BHA (Run #10) M/U tapered and string mill on B & 0 jars- laid down 2- 3 1/8" DCs damaged during M/U. B/O over -torqued x -over sub from BHA- changed out Gill 600s f/ Gill 500s- changed out M/U and B/O dies in tongs (2 3/8" / 2 7/8"). Continued M/U BHA #10 (4 1/8" x 11/4" tapered mill, 3 3/4" x 1" bit sub, 4 1/8" x 1" string mill, 3 1/8" x 11/4" B & O jars, 3 1/8" x 11/8" x -o sub, 4- 3 1/8" x 11/4" DCs, 3 1/8" x 11/2" x -o sub, 3 1/8" x 11/4" Acc jar, 3 1/8" x 11/16" x -o sub = 155.08). TIH w/ BHA #10 on 2 7/8" 7.9# P-110 PH -6 workstring to 5,627'- worked next 3 stands twice thru interval that test pkr was hanging in (5,688- 5,810')- no bobble on indicator up or down. Continued in hole to 7,935' (128 stands). SOW 48k PUW 60k. Lined up and circ hole volume plus (7000 stks) at 3.9 bpm 1670 psi. No solids over shaker. B/0 Kelly hose and pumpin. POOH w/ BHA #10 pumping displacement every 10 stands. 11/08/18 -Thursday Cont. POOH w/ 41/8" string mill assy f/ 5871', L/D BHA, no wear on milling assy. Clean & clear floor & rig maint. while waiting on packer arrival. M/U 4" Arowset I -X test pkr f/ 5" 18# casing- TIH to 618'. Serviced rig. Cont. TIH f/ 618' to 7,857' (no issues at liner top or thru 5" 18# casing). Set pkr at 7,857' w/ 20k weight on pkr. Pressured up to 2500 psi on annulus and held on chart f/ 40 mins- good test- bled off pressure. R/D testing equip- prep to POOH. POOH f/ 7,857' to 5,487' (pulled 39 stands). Slipped & cut 88' of 1" drill line (trouble with 2- cable cutters)- reset crown-a-matic. Finished POOH f/ 5,487' w/ Tripoint test pkr. B/D tools. Changed out tongs- P/U swivel to B/0 subs to make room for gun basket- prepping floor to P/U TCP assy. Hilcorp Alaska, LLC Hil�rorp Alaska, Ll.0 Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MGS A41A-11RD2 CT/ Rig 404 50-733-20179-03 195-119 10/8/2018 1 11/13/2018 11/09/18 - Friday Cont. prep t/ p/u TCP guns, m/u safetyjoint, I/d tongs & arrange deck for gun baskets. P/U 3 1/8" SDP TCP guns, 6 SPF, 60 deg phasingt/1455'. Continue TIH w/ TCP assy on 2 7/8" 7.9# P-110 PH-6 workstring- 1845 hrs go thru TOL at 5,654' w/o seeing it. Continue in to 10,089' (142 stands + single). Pulled and L/0 single placing EOT at 10,056'. PUW 73k SOW 43K. R/U Pollard ELine- Run #1 TIH w/ 13/8" RS, 111/16" wt bar, 111/16" GR/CCL to 8,700'- logged up to 8,000'. Sent files to Eng group- POOH R/D ELine. Corrected log as directed and moved perf assy uphole 40'- discussed procedure with crew- closed annular, checked line up and dropped bar- — 5 min wait for detonation- perfed 8715'- 8733', 8750'- 8795', 8820'- 9018', 9038'- 9312', 9367'-9480', 9497'- 9790', 9824'- 10015'. Monitored press (0) then CBU @ 3 bpm 70 psi w/ 45BPH loss. Shutdown pump, well on vacuum. Blew down lines- began POOH laying down 2 7/8" PH-6 workstring, t/8173', pumping 11/2 displacement every 20 jts. 11/10/18-Saturday Continued POOH laying down 2 7/8" 7.9# P-110 PH-6 workstring f/ 8,173'to TCP assy at 1,424'. Serviced and lubed rig. M/U safety joint and began laying down TCP asst' f/ 1,424'to 701'. Suspended operations due to weather impairing safe operations (Blowing snow w/ winds at 40 mph+ impaired moving tubulars & visibility) Performed housekeeping and organizing. Snow stopped-finished B/D L/O TCP assy in basket at btm of beaver slide- all shots fired. Clean/clear floor prep to P/U completion - R/D Gills R/U McCoys- strapped 1st row of 2 3/8" tb. 11/11/18-Sunday Cont. r/u t/ run 2 3/8" completion tubing. Assisted Tripoint M/U production pkr w/ hardware (as per schematic) on 2 3/8" 4.7# L-80 EUE 8rd tb to 2 7/8" x- over sub @ 2,264'. Placing GLMs as directed. Changed running equipment to 2 7/8". Continued in hole P/U 2 7/8" 6.5# L-80 EUE 8rd tb, strapping, drifting, torqueing to specs (placing GLMs as directed)- from 2,264' to 5830', did take weight at liner top put half turn in string & bounced in, currently took weight @ 5830' working to fall through. 11/12/18 - Monday Continued RIH w/ completion string f/ 5,810' to 7,120', having to work 1/2 RRHT in string to get past 5,830' 6,132', 6,226', 6,285', 6,616' & 7,715' (overpull not an issue- PUW 38k SOW 32k). Serviced rig. Continued in hole f/ 7,120' to 7,859' (SOW 34k PUW 41k). Rig crew assisted Mr. Chanley in M/U tb hanger- plumbed 2- control lines thru- lowered and landed hanger putting EOTs @ 7,903'. Ran in lock down pins. Began clearing and cleaning rig floor for dismounting while waiting on S/L equip. Worked M/V Resolution receiving Pollard S/L unit (backloaded 2-gun baskets, Pollard E/L equip and 1-jet heater). R/U S/L w/ pumpi n, WL rams & packoff- (Run #1) M/U 11/2" tool string w/ rope socket, 10' of stem, knuckle, oil & spa ng jars w/ 1.85" AD-2 Stop-TIH and tagged plug in 'X' nipple at 7,871'- no problem. POOH rigged S/L to side. Dropped bar. Tied in Kelly hose and setup to chart pkr setting and tb test. Pressured up to 3800 psi (bypassed standpipe due to leak) and held for 15 mins- lost 100 psi in 15 mins- Tripoint approved set-packer @ 7827', bled off pressure and repaired leak at floor- pressured up to 2700 psi and charted for 43 mins- Good. Bled pressure down to 1500 psi on tb. Lined up on 7" x 5" annulus- pressured up to 1700 psi and held on chart f/ 33 mins- good. Released pressure. R/U S/L, TIH w/ same 11/2" tool string plus 2" JD pulling tool- failed to latch on two runs in hole. Continued cleaning on pits and R/D misc items during S/L work. 0400 hrs Run #4 same tool string w/ 2" JU pulling tool- RIH to 7,871' and beat down on prong- POOH w/ recovery. Broke off JU tool and M/U 2" GS pulling tool-TIH (Run #5) to 7,871' Pull plug t/ surface. 11/13/18-Tuesday R/D wireline. Pull landing jt & install BPV, Flush stack, surface lines & eq. w/ fresh water, blow down same. Coadco r/d PVT system. R/D floor/stairs, prep & scope down derrick, I/d same. Prep t/ N/d BOPE. Total safety r/d gas detection system. N/D BOPE, stripper head & annular. Continue with N/D of mud cross and riser while diagraming derrick cabling before removing same for derrick inspection. Lowered tree into well room and N/U same- void tested 250 low 5000 high. 2300 hrs began loading workstring along w/ vendor iron on M/V Resolution. Winterized test pump. Pulled BPV and installed 2WC- shell tested tree to 250 low 5000 high- pulled 2WC-turned well over to production at 0100 hrs. Continued dismantling and cleaning W/O package for demobe. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 09,2018 TO: Jim Regg P.I.Supervisor 9 51q(re, SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC A41A-11RD2 FROM: Adam Earl MGS A41A-11RD2 Petroleum Inspector Src: Inspector Reviewed By�: � P.I.Supry JLC% NON-CONFIDENTIAL Comm Well Name MGS A41A-11RD2 API Well Number 50-733-20179-03-00 Inspector Name: Adam Earl Permit Number: 195-119-0 ' Inspection Date: 5/5/2018 Insp Num: mitAGE180509131138 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ' A41A-11RD2 -'Type Inj W'TVD 7612 " j Tubing 3600 PTD 1951190 Type TestSPTTest psi 1903 IA 3450 BBL Pumped: 0 'BBL Returned: 0 - OA so 4YRTST � P/F 1 Intervall �� F Notes: This test failed before it started.While recording pre-pressures,after starting with the O/A,SOpsi.,the operator informed me of a bad gauge on the I/A.It was stuck on 400psi after removing it to install test gauges.The test gauge read 3,450psi.on the I/A.Injection pressure on the tubing read 3,600psi.I had the operator shut in the well pending instruction from Anchorage. SCANNED I. Wednesday,May 09,2018 Page 1 of 1 • • From: Patricia Bettis To: Well History File Date: February 9, 2017 Re: Well Name Change (PTD 195-119) At the request of Hilcorp, the well name for MGS A41A-11LN was changed to MGS A41A-11RD2 effective February 9, 2017. scosEu JUN 0 2 2017 0 • . CU MO t Cle •W4- I __________________ -0 11 ommul U w am t) R3 to R3 imo CU Q -0 s r oNw Q z 1.lID- I i 1 W 1 Lial Q -311Q1f.,. .- --, 2,‘„,-_..,.....,,wip usi- "--IN1• :mss ,.Y 411r)__ ! �� ! c n in �' ivolimphonso +� �_�'�. *tom - itili 44110 N = 1 0 0 a' 1 -1--( e-1 e� Q e1 Cr Q • ! a) II E al Z N 0 GJOC 3 '.I ri3 ci Z a X 'O ci X a)DA 0 • C X rD O t = X U 4- N a) O X ++ O E 0 w 1C C Ca a) > i aJ i C O '+, Y p- U E U +O+ a1 v Cra C i O 4-' Z (�6 a) U i 1 'a DI U U DA Dro Ca C as L CD 4-, a, E CA -.7:3 a1 +J C S. Ca Q N M C N N o6 o2S QS a a a +, +.• C C a) a) N E E ra - 0. a) 1 ) O O U 0 0 a) 0 oN N a o) LbL LID o0 01 o Oo 0 O o 0 O O 9 O O 01 01 Q1 M F,_ N N N N < O o O O N N N N M M M M G M M m M 4-+ N N N N N O O O O 2 L Lr) UI ir) W I - I 1:11 a) 3 E 73 CD cac 3 I Z . z � I v O J C o Q Q N o N N Q Q Q Q • . Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, February 09, 2017 10:23 AM To: Larry Greenstein (Igreenstein@hilcorp.com) Subject: MGS A41A-11 LN (PTD 195-119) Larry, Per Hilcorp's request date (1/26/2017),the AOGCC is changing the name of MGS A41A-11LN to MGS A41A-11RD2. Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue SCANNEDJUN 0 2Z017 Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use'of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Thursday,January 26, 2017 9:18 AM To: Bettis, Patricia K (DOA) Subject: FW: Middle Ground Shoal - Last Three Well Name Changes Attachments: 20170113 MGS Well Name Changes.xlsx; MGS A34-11 name change.pdf; MGS A41A-11 name change.pdf; MGS C32-23 name change.pdf; Swanson River Well Naming Conventions diagram.pdf Hi Patricia Did the explanation below of the problem with showing all the old holes on a single schematic make sense?? Would you like to discuss the options for changing the well names to something more appropriate to the API number than using the lateral designations?? These last three wells are the most confusing of the name changes because the first sidetrack changed the well number completely due to the new bottomhole location (using the federal naming convention method—attached above). That naming convention has caused problems for SRF wells too, but it is what it is and we find a way to make it work even though there are a good number of exceptions to the basic naming rules. It's why I summarized the abandoned completions on the schematic with dates and APIs rather than draw them in. Call me anytime to discuss and thank you for working through all these name changes. Larry 777-8322 From: Larry Greenstein Sent: Friday,January 20, 2017 2:02 PM To: 'Bettis, Patricia K(DOA)'<patricia.bettis@alaska.gov> Subject: RE: Middle Ground Shoal: Well Name Changes Understand, Patricia I was trying to get these name changes done with historical information so we can get on with making the new well signs for the platforms. For a 'clear and understandable public record' we unclutter most all of our schematics to show only the current producing or injecting wellbore, not all the lost holes, P&A'd completions and previous well names. They can just get too busy for a single sheet of paper. We continually try not to confuse people, that use the schematics, with obsolete information crammed on the page. As you allude, the current wellbore sketch is what we build for public use. With proposed schematics (like the KRU 1B- 15A schematic you included), we do show the current and proposed future wellbores. Once completed (ie the original wellbore has been abandoned) and reported, we show only the current wellbore on future schematics (as with KRU 1B- 15A pgs 6 & 29 in your electronic well files). Imagine carrying this on when there are 4 or 5 sidetracks in the historical record. There's no way to show all that on one page. This is different from a multi-lateral well, where you have a number of currently active completions (.60, .61, .62 etc). These would be shown on the schematic branching off of the mother wellbore as they are open for production/injection. Are you sure you want all this extra abandoned information on the current wellbore schematic?? This isn't meant to be an as-built, it's a schematic to know what's looking at you when you run into the well with wireline tools. That's why I took our 1 • current schematics and added the historical references to previous abandoned versions of the well to the existing wellbore on the schematics. Larry From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday,January 20, 2017 11:07 AM To: Larry Greenstein <Igreenstein@hilcorp.com> Subject: Middle Ground Shoal: Well Name Changes Larry, Please see highlighted paragraph. For a clear and understandable public record, Hilcorp needs to provide a current wellbore sketch for C34-11LS2,A41A11LN, and C32-23LW that shows all sidetracks drilled from the original well. The original well and all sidetracks need to be clearly labelled. I have attached a simple example from the Kuparuk River Unit of such a sketch. This wellbore sketch shows the original wellbore and the initial proposed sidetrack. Other sidetracks or lateral could be added in the future to this sketch to show the progression of the wells' history. Thanks, Patricia From: Bettis, Patricia K(DOA) Sent:Thursday,January 12, 2017 11:40 AM To: Larry Greenstein (Igreenstein@hilcorp.com) <Igreenstein@hilcorp.com> Subject: Middle Ground Shoal: Well Name Changes Larry, I'm in agreement with all the requested well name changes, except: C34-11LS2,A41A11LN and C32-23LW. The first sidetrack from each of these wells had a name change from the original well drilled. For example, C24-14 was drilled. It was later sidetracked and that sidetrack was renamed C32-23. The second sidetrack was named C32-23LW. This would make the revised name C32-23RD2, which agrees with the API No. 50-733-20251-02-00. For C34-11LS2,A41A-11LN, and C32-23LW, please provide a current wellbore sketch of each well that shows all sidetracks drilled from the original well. Please label the original well and all sidetracks. Thank you, Patricia 2 /� 4..._ C� /-t • Middle Ground Shoal II ee n /� p Well:MGS A41A-11LN Last SCHEMATIC I V Ifs Ia (PTD: d:2006-02-24 ( ii ileum Alaskn,LI.0 API:50-733-20179-03 KB:38' Water Depth 73'MSL CASING DETAIL I1...,: L 1Size Wt Grade Conn ID Top Btm Cement ' ' ' R 2 • 'I 20" Surf 330' 13-3/8" 61 K-55 12.515" Surf 1,990' 810 sx 20' ' 7" 26 N-80 6.276" Surf 1,659' 7" 29 N-80 6.184" 1,659' 7,765' 824 sx 5" 18 P-110 511 4.276" 5,654' 10,743' S60 sx t 13-3/8" 3-1/2" 9.3 1-55 BTC 2.992" 10,680' 12,045' (slotted) TUBING DETAIL RTS-G 2.323" 38.60' 324.25' 2-7/8" 7.9 1-80 SLHT 2.323" 324.25' 8333.43' RTS-6 2.323" 8333.43' 8401.53' I, •4( JEWELRY DETAIL I No Depth Depth ID OD Item (MD) (TVD) i 1 38.60' CIW TYPE DCB tubing hanger,SS,2.5 Type II profile 2 322' 322' 2.188" 3.520" Otis R Nipple 3 8,335' 7,602' 2.188" 3320" Otis R Nipple j,, ',! 4 8,344' 7,608' 2.400" 3.970" Baker SABL-3 Perm Packer w/K Anchor Seals 5 8,392' 7,641' 2.010" 3.530" Otis RN Nipple •S 6 8,402' 7,647' 2.323" 3.470" WLEG I,, :;- �GA-•{�I A 5,654' 5,209' Isolation Packer PERFORATION DETAIL ?'� ;x;11-"� Top Btm Top Btm 7, '' , Zone (MD) (MD) (TVD) (TVD) FT Date Status R 3 '1 AS 6,084' 6,136' 5,595' 5,642' 52' Isolated I;��-� s/4 FL(1) 6,574' 6,638' 6,040' 6,098' 64' Isolated '' ' � , FL(2} 6,659' 6,677' 6,117' 6,134' 18' Isolated i'i; 8 i RN_ 5 �,;• "} FP 6,746' 6,772' 6,197' 6,221' 26' Isolated I`;/ t FS(1) 6,845' 6,857' 6,288' 6,299' 12' Isolated j 7 ii i , FS(2) 6,870' 6,881' 6,311' 6,321' 11' Isolated G8(1) 7,157' 7,230' 6,577' 6,645' 73' Isolated "' GB(2) 7,251' 7,289' 6,665' 6,701' 38' Isolated ',' r'''' HZ-HR 10,530' 10,666' 9,029' 9,134' 136' Open JI I ►: 5" I I - 0' I I Slotted Liner: I I HR-HN,HN-HK,HK-HI,HI-HE&HE-HC D S yYt)0144 t t!z-e .`I I I ,r 1 I (,yt r,,��wet( /1 7:)------6) / !( C�01 .mo I Inii@ I e____ __ .7, _ /t- a / 4 at-P I , 03) 1n -pp jl J'A, I?I' gt - kil ..-( MID TD=12,047' 1// `,4 .D l - y • �/� ,., `� ttes`‘da yiA jAvt_te: (4,,x4 s _7/ R D '3 Updated By:11.1.02/05/16 • 1 PLGGING & LOCATION CLEARANCE REPORT State of Alaska ALASKA OIL & GAS CONSERVATION COt44ISSION PTA No. 69 -020 Lease A('L t97- 1 Memorandum To File: API No. /31 - 2 C2/yy - O Cl Well Name Mrs 44 - 2 21 Operator Location 5e2c. /, Teo, (Z.0 Abnd Date 3/07/A6 Spud: ,3'/?0/69 , TD: jl82 p , Completed .c/ /6 9 Note casing size, wt, depth, cant vol, & procedure. arc Cag: 6r d @ 2 2 2p' w//q,a Long Cog: 9%8 obff.dirr N /o $3- win ?a it% Liner: 7 a c /0/8/2 - at 69t vl Pert intervals - tops: /4 Gitc - )1-I-ev v-aIs - !4689' Review the well file, and comment on plugging, well head statue, and location clearance - provide loc. clear. code. Plugs: , R /Of '5O S z- c✓f 43x Sy 98 sF ah �Crf?• - 7)C MA 9 3 !00 sx /a 69 ? (o 4/6 +a ,c-t- /c9 L. C"( CSP QTc c4 R 9%8 00;`�fi( ado()IA rib -6 VI)1 p vr-r 300- /1(7 / z 75' Well head out off: - Marker post or plate: Location Clearance: — "Conclusions:,j )el( Br[/ 9QC! 12 7 / - 22A - •! P(216116' 4 --TG 9 (ca.,ce/142 l-/ 9 G-s 64 — 11(4 '11 P 1-9 SG-0 2 -- Code , Signed .44,A:,,..„6,6..";:;4,_,O Date -r12619J Yon at A\gan\lo-apti, rev$/21/0$ XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages' [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by:~ianna TO RE-SCAN Vincent Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ MEMORANDUM To: Jim Regg ~ P.I. Supervisor k ~~z ~ ~1 ~;~io FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 12, 2010 SUBJECT: Mechanical Integrity Tests XTO ENERGY INC A41A11LN MGS A41A11LN Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv J Comm Well Name: MGS A41A11LN Insp Num: mitCS100508075826 Rel Insp Num: API Well Number: 50-733-20179-03-00 Permit Number: 195-119-0 Inspector Name: Chuck Scheve Inspection Date: 5!3/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well AalAl1LN Type Inj. w ° TVD 7612 ~~~ IA o zzoo ~' zzoo zzoo P.T.D 195119°~ TypeTest SPT Test psi 1903 '' pA to to to to Iriterval4YRTST per, P / Tubing 3600 3600 3600 3600 Notes: .. Wednesday, May 12, 2010 Page 1 of 1 • • Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) 2~~zt~,/,t~ Sent: Monday, February 01, 2010 10:06 AM To: 'Jeff_Gasch@xtoenergy.com' Cc: Barney_Phillips@xtoenergy.com; Cod~Mishler@xtoenerg .com; Greg_Duggin@xtoenergy.com Subject: RE: XTO Energy - A11-13RD2 (181-060) & A41A-11L (19 -119) Thank you for the recent injection rate and pressure histories. Your request to delay MITs on A11-13RD2 and / A41A-11LN until May 2010 is approved. Jim Regg AOGCC c~ ~* ~~ r ~~'~~~~!~9~~~~ ~~~ 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Jeff_Gasch@xtoenergy.com [mailto:Jeff Gasch@xtoenergy.com] Sent: Friday, January 29, 2010 1:59 PM To: Regg, James B (DOA) Cc: Barney_Phillips@xtoenergy.com; Cody_Mishler@xtoenergy.com; Greg_Duggin@xtoenergy.com Subject: XTO Energy - A11-13RD2 (181-060) & A41A-11LN (195-119) Jim, Barney Phillips spoke with you earlier this week about delaying the MIT's on the A11-13RD2 (181-060) & A41A- 1 LN (195-119) so they can get back on schedule with the rest~f oar injection wells. I've attached a file o tf he injection rate and pressure history for both wells. The A11-13RD2 MIT is due in February and the A41A-11LN is due in March. What we would like to do is delay the MIT's for both of the wells until May, when the MIT's for other injection wells on the platform are due. This will save time for XTO and the inspectors by eliminating two trips to the platform for witnessing just one well. Let us know if this acceptable. Thanks, Jeff Gasch Production Engineer XTO Energy Office # (432) 620-6742 Cell # (432) 638-7433 Fax # (432) 687-0862 2/1/2010 XTO Energy - A11-13RD2 Rate and Pressure History (~yJ -~(-Q~~ 500 450 400 a N ~ 350 c c Q ~ 300 x a~ v 250 a 200 as u c 150 d 'c 100 50 0 9/1 /2009 4000 3800 3600 3400 ~. .N 3200 ~" d 3000 ~ a c 0 2800 y .~ 2600 2400 2200 2000 • • 9/21 /2009 10/11 /2009 10/31 /2009 11 /20/2009 12/ 10/2009 12/30/2009 1 /19/2010 1000 900 800 a N ~ 700 c c Q ~ 600 x v 500 a ~ 400 d ... c 300 r d ._ 200 100 0 9/1 /2009 XTO Energy - A41A-11 LN Rate and Pressure History (~~ SRS'- ct~ 4000 3800 3600 3400 .-. .N 3200 ~' d w 3000 ~ a 0 ~. 2800 d .^ c 2600 2400 2200 2000 L~ 9/21 /2009 10/11 /2009 10!31 /2009 11 /20/2009 12/10/2009 12/30/2009 1 /19/2010 ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg "-.!l S j;jZt? ,.. (! /..¡c;¡, P.I. Supervisor '~ '1', DATE: Thursday, April 06, 2006 SUBJECT: Mechanical Integrity Tests XTO ENERGY INC A41AIILN MGS A41AIILN Src: Inspector ~~ \~/ Reviewed By: P.I. Suprv ,':\t12-- Comm FROM: Jeff Jones Petroleum Inspector NON-CONFIDENTIAL Well Name: MGS A4IAI1LN Insp Num: mitJJ060312133707 Rei Insp Num API Well Number 50-733-20179-03-00 Permit Number: 195-119-0 Inspector Name: Jeff Jones Inspection Date: 3/11/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well A41AIIL Type Inj. w TVD 7616 I IA 0 2000 2000 I 2000 N I P.T. 1951190 TypeTest SPT Test psi 1904 I OA 38 38 38 38 _..-_._--_.~------ Interval INIT AL P/F P Tubing 3600 3600 3625 3625 Notes Bill Fischer performed the MIT today in a safe and proficient manner. The platform & well room appeared clean, orderly and in good condition. SCAANED MAY () ,9 200a Thursday, April 06,2006 Page I of I e e Jl!R " '-'. "'t~ ,:¡,.t;n"t:.':,; "~v~~,,,,;,;,· " f'",Y XTO Energy Inc. 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) March 23,2006 'f \\0.... \()\ Alaska Oil and Gas Conservation Commission Attn: Mr. John Norman 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Well Operations Report: Well #A41A-llLN - Repair Press Communication Dear Mr. Norman, XTO Energy, Inc. hereby submits its Sundry Operations Report (Form 10-404) for the workover performed on the injector well #A41A-IILN. This well is located on Platform A, in the Middle Ground Shoal Field of Cook Inlet, AK. The completion was replaced with a new injection packer & tubing string. The well passed the MIT test on 3-11-06. ' Please find attached the following information for your files: 1. Form 10-404 Sundry Well Operations Report 2. Daily Report of Operations 3. Present Wellbore Schematic If you have any questions or require additional information, please contact me at (432) 620-6743. Sincerely, 9 ç...L A 0/ Paul L. Figel Engineering Manager Cc: Scott Griffith Tim Smith .. STATE OF ALASKA A ALA..,. OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS Kt:GEIVt:D MAR 2 4 2006 Alaska Oil & Gas Cons. Commission 1, Operations Abandon Performed: Alter Casing D Change Approved Program D 2. Operator XTO Energy Inc. Name: Suspend Repair Well 0 Pull Tubing0 Operation Shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: Development D Stratigraphic D ExploratoryD Service 0 Perforate Waiver Stimulate0; Time ExtensionD Re-enter Suspended Well D 5. Permit to Drill Number: 195-119 ; 6. API Number: 50-733-20179-03 ; Other 3. Address: 200 N. Loraine St. Suite 800 Midland, TX 79701 7. KB Elevation (ft): 38' 8. Property Designation: Platform "A", Leg 2, Cond 12, 1677' FSL & 367' FEL, S11, T8N, R13W, S.M. 11. Present Well Condition Summary: 9. Well Name and Number: A41 A-11 LN ' 10. Field/Pool(s): Middle Ground Shoal Total Depth measured 12,047 true vertical 10,046 feet feet Plugs (measured) NA Junk (measured) NA Effective Depth measured 11,988 true vertical 10,014 feet feet Casing Structural Conductor Surface Intermediate Liner 1 Slotted Liner 2 Length Size MD TVD Burst Collapse 7" 1990' 7765' 10743' 12045' 1934' 7151' 9196' 10045' 3090 7240 13940 Slotted 1540 5410 13450 Slotted 1990' 7765' 5089' 1365' 13-3/8 " 5" 3-1/2" Perforation depth: Measured depth: 10,530' - 12,045' True Vertical depth: 9044' - 10,045' Tubing: (size, grade, and measured depth) 2-7/8" L80 7,9# @ 8,402' Packers and SSSV (type and measured depth) Baker 5" SABL3 Perm Pkr, NA for SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10,530' - 10,666' & 10,743' - 11,988' Treatment descriptions including volumes used and final pressure: Pumped 204 bb110% HCL @ 2 BPM @ avg press 3200 psi. Final Press = 3117 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure NA NA 474 3975 NA NA 1141 0 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Tubing Pressure 3625 3600 15, Well Class after proposed work: ExploratoryD Development D 16. Well Status after proposed work: oilD Gas D WAG D 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 0 x GINJ D WINJ 0 WDSPL Sundry Number or N/A if C.O. Exempt: 305-383 D Contact Paul Figel Printed Name Paul Figel Title Engineering Manager Signature Date 3/23/2006 Form 10-404 Revised 12/2003 A> Ý.~.D' ;[!~ MGS A41A-11LN WIW Cook Inlet, Alaska Leg 2, Conductor 12 API No.: 50-733-20179-03 Sidetracked: 8-6-95 A22·01 was P&A'd for the A41A·11 that was Spud in 3·7·86. 20" Conductor Csg @ 330' Surf Csg: 133/8",61#, K55. Set @ 1,990'. Cmt'd wI 810 sk. Top Job wI 170 sk. Intermediate Csg: 7", 26-29#, N80. Set @ 7,765'. Cmt'd wI 824 sk. 26# : Surf - 1,659' 29#: 1,659 -7,765' Liner: 5", 18#, P110 STL. Set @ 10,743'. TOL @ 5,654'. TOL has isolation packer. Cmt'd wI 560 sk. e Liner: 3-1/2" 9.3# J55 BTC slotted. Set @ 12,045'. TOL @ 10,680'. 2-19-06: Clean out fill to 11,988' MD (10,014' TVD) TD:12,047' MD (10,046' TVD) e PLF 3-23-06 KB: 38' Water Depth: 73' MSL Tbg: 2-7/8" 7,9# L80 RTS-6 & Seal-Lock HT set @ 8,402' on Feb '06 9 Jts 2-7/8" 7.9# L80 RTS-6: Surf - 322' 2-7/8" Otis R Nipple (2.188" ID) @ 322' X-over 2-7/8" RTS6 Bx X Sea I Lock HT Pin @ 323' 295 Jts 2-7/8" 7.9# L80 Seal Lock HT tbg X-over 2-7/8" Sea I Lock HT Bx X RTS6 Pin @ 8,333' 2-7/8" Otis R Nipple (2.188" ID) @ 8,335' 8' Pup Jt 2-7/8" 7.9# L80 RTS-6 @ 8,336' Baker K anchor wI seals L80 @ 8,343' 5" Baker SABL-3 Perm Pkr (30-24) 9Cr @ 8,344' 6' 3-%" MOE VAM Pin 9Cr @ 8,349' X-over 3.5" VAM Bx X 2-7/8" RTS-6 Pin @ 8,354' 6' Pup Jt 2-7/8" 7.9# L80 RTS-6 @ 8,355' 1 Jt 2-7/8" 7.9# L80 RTS-6 @ 8,361' 2-7/8" Otis RN Nipple (2.01" ID) @ 8,392' 8' Pup Jt 2-7/8" 7.9# L80 RTS-6 @ 8,393' WLREG @ 8,402' Isolated Perfs in 7" behind 5" liner: - AS 6084'-6136' FL(1): 6574'-6638' FL(2): 6659'-6677' FP: 6746'-6772' FS(1): 6845'-6857' FS(2): 6870'-6881' GB(1): 7157'-7230' GB(2) 7251'-7289' HZ-HR: 10,530'-10,666' @ 6 spf Slotted Liner: HR-HN, HN-HK, HK-HI, HI-HE & HE-HC. /' e e 1 XTO ENERGY INC. Daily W orkover Report Objective: Repair Press Communication & Acid Stimulation First 01/31/2006 Report: 1/31/06 RU WL. RIH & pulled dummy GLV #7 @ 8,353'. POOH. RD WL. Derrick moving from slot 14 to slot 12. 2/1/06 Rig accepted @ 18:00 Hours 1-31-06. RU circ lines to WHo Mix up 20 bbl sweep. WHP = 0 psi. TCA = 250 psi. Pmpd visc sweep & chased w/FIW down TCA. Took rtns (diesel on backside) to prod @ 2 BPM & 700 psi. Diverted rtns to flow-back tank. Circ until rtns clean. Monitored well. No flow. Set BPV. ND WHo 2-7/8", EUE tbg thrd corroded on tbg hanger. Clean up & tap threads. Lwrd riser & NU BOP's. 2/2/06 NU BOP & flow line. Pulled BPV. Install 2-way check. RU test assembly. Tstd BOP to 250/5,000 psi. PT Hydril to 250/ 2,500 psi. Tstd accumulator. Tested gas alarms. (Jim Regg of AOGCC waived witness of tests.) LD test assembly. Run dry rod in stack, screwing into 2-way check. Dry rod twisted off. LD rod. Removed drill nipple, choke & kill lines. Lifted BOP/riser. Remove xo fr hanger. Checked 2-way valve. Lowered BOP/riser. MU DSA. Installed drilling nipple, flow, choke & kill lines. 2/3/06 Fin NU MU landing jt & screw in hanger. Test BOP/riser to 250/5,000 psi. Pulled 2- way ck. Spear hanger. Back out lock down pins. Pulled 80k on tbg. Appears seals came out of pkr. LD hanger. RU & circ BU. RU to LD tbg. POOH LD tbg (checking for norm, SLM). Rec'd 172 jts 2-7/8" 93 jts 2 3/8", 7 GLM's w/ pups, 2-X nipples & Seal assembly. RD tbg equip. PU kelly. Test valve to 250/5000 psi. LD kelly. Set wear ring & PU pkr milling BHA. 2/4/06 RIH w/ pkr milling BHA on 2-7/8" DP. X-over 3-1/2" DP. Cont RIH. Tagged pkr @ 8,420'. PU Kelly. Milled pkr @ 8,420'. Problem w/ rotary table. Unable to rotate. Trouble shoot. Current limit control malfunction. Milled on pkr until it dropped. Pushed down 40'. LD kelly. Pushed pkr down to TOL. 2/5/06 Pushed pkr to 10,615' (TOL). Circ BU Monitored well. POOH w/ mill BHA. MU spear. RIH w/ spear BHA to 10,550'. Wash down & spear fish @ 10,615'. POOH slowly w/ fish in 5" liner. Cont POOH. 2/6/06 POOH w/ spear BRA. LD fish. Recd sealbore ext, 2 jts 2-3/8" tbg, nipple & WLEG. CO jars. Packed offw/ soft scale. MU overshot BHA w/ 1-11/16" grapple. PU 12jts 2- 1/16" tbg. RIH w/ overshot BHA on 3-1/8" DC's, 2-7/8" & 3-1/2" DP to 10,456'. RU to wash down stands. Unable to circ. PUR. LD 15 jts 3-1/2" DP. Tried to circ. DP e e 2 plugged. PUR @ 9,340'. DP unplugged. Flow U-tbg out DP. Break circ. Shut in. Rev circ hole vol @ 9,340' @ 3 BPM @ 1,000 psi. RIH while reversing DP vol @ 9,617' & 9,897'. Cont staging in hole reversing DP vol @ 10,085', 10,270' & 10,456'. Wash down & rev circ DP vol @ 10,582' & 10,703'. 2/7/06 Stage in washing scale & reversing DP volumes @ 10,703', 10,797' & 10,936'. Cont washing down to 10,892'. Rev DP. Wash down & unable to pass 11,031'. POOH wi overshot BHA. LD 33 jts of 3-1/2" DP. Stand back 3-1/8" DC's & 3 stds 2-1/16" tbg. Check overshot. Btm of OS is dented & curled in. Break off OS. RIH wi 2.8" milllmotor BHA on 2-1/16" tbg (46 jts). 2/8/06 RIH wi 2.8" milllmotor BHA. Circ into 5" & 3-112" liners. Tagged up @ 10,782'. Unable to work DH wi mill. Motor stalls out. POOH wi 2.8" mill. Break off 2.8" mill. MU tapered mill (2" to 2.7") & string mill (2.7"). Rill wi mill BHA. Tagged @ 10,885'. Milling tight frl 10,828' to 10,833'. RIH & tagged up @ 11 ,023'. Milling @ 11,019'. 2/9/06 Milled 3-1/2" liner fr/11,019'-11,025' . Made last 2' in 6 hrs. Will lose l' if mtr stalls. Con't milling to 11,025' wi 1-2K #'s WOB pmpg 1.5 - 1.7 BPM @ ± 800 psi. Acting like liner is partially collapsed. Made short trip to 3-1/2" TOL. Tight spot @ 10,830' taking 20K over-pull. Did not see tight spots while TIH. Milling @ 11,024'. Made 1/2' in 3 hrs. Pmpd dry job. POOH wi mill BHA. No tight spots POOH. RU 2-1/16" equip. Cont POOH. Stand back 2-1116" tbg. Break off & inspect mills. Tapered mill was ±80% worn. String mill was 30% worn. RU up BOP test assbly. Tstd BOPE to 250/5,000 psi. 2/10/06 Tstd BOP & Hydril to 250/5000 psi. Tstd accumulator & gas alarms. Jim Regg of AOGCC waived witnessing BOP test. RD test assbly. RIH wi 2-1/16" mule shoe to 10,650'. Cut 100' drilling line. Rill & tagged @ 11,027'. Washed tight spot frl 11,027' to 11,034' pmpg 5.5 BPM @ 3,300 psi. Cont washing down frl 11,034' to 11,125' (tight spot @ 11,116' & 11,125'). Worked @ 11,125' with pushing & pmpg sweeps. Appears muleshoe is damaged or plugged. SI pipe rams. EIR @ 1.5 BPM @ 2,700 psi wi FIW. RU to pump acid. Pmpd 20 bbls 10% HCL. Flushed to EOT + 5 bbls FIW. Injected acid & overflushed by 50 bbl @ 1.5 BPM. Press dropped 200 psi on acid and slowly incr to 3,100 psi. 15 min SIP dropped 1,300 psi. Bled-off well. POOH (tight @ 11,030' 30K overpull). Pmpd dry job. POOH wi mule shoe. 2/11/06 POOH wi 2-1/16" mule shoe. Mule shoe was dented & damaged. MU motorlmill assembly (2.5" OD string mill & 2.0" x 2.5" OD step mill). Rill wi mill BHA. Tagged up @ 11,030'. Washed & milled fr 11,030'-11,080'. Tight spots 11,030', 11,061' & 11,080'. Cont milling fr 11,080'-11,121'. Tight spots @ 11,115',11,119' & 11,121'. 2/12/06 Mill 3-1/2" liner wi 2.5" OD milling BHA @ 11,121'. Had pump press incr. Unable to get pressure to drop off. POOH wi mill BHA. No tight spots POOH 3-1/2" liner. LD mtr/mills. Tapered step mill 118" under gauge & string mill full gauge. RIH wi new motor wi 2.0" x 2.5" OD step mill & 2.5" string mill. Change out 6 joints 2-1/16" tbg. tit e 3 Tagged @ 11,121'. Clean out 3-1/2" liner. Mill fr/11,121'-11,139'. At 11,139' stacking weight but not getting differential from motor. Short trip to top 3-112" liner. Rlli back to 11,139'. Milling @ 11,139'. 2/13/06 Milling 3-1/2" liner fr/ll,139' - 11,172'. Stacking weight wI no differential. Short trip to top 3-1/2" liner. Tight spots @ 11,125' & 11,030' on trip out & 11,165' trip in. Mill frIll, 172' - 11,185'. High differential on motor but not stalling out. Dropped ball to shift circ sub open. Circ gel pill @ 4 BPM @ 2,100 psi. POOH wI mill BHA wI no tight spots. LD & inspect mills. Tapered & step mill was full OD. Nose of step mill had 2 pieces of fish disconnect stuck inside. Only the nose on mill was worn down. Rlli wI overshot wll - 11/16" grapple. OS wi extensions is 7' x 2-5/16". 2/14/06 Rlli wi overshot. Wash dwn to 11,185'. Had 100 psi pump press incr. Set down 20K. PUR & tried to pump. Had same 100 psi pump incr. POOH wi overshot BHA. LD OS. No fish recovered. MU motor & 2-1/16" wash over shoe jt wi cutrite. RIH wi wash over BHA to 11,150'. Tagged @ 11,187'. PU 2'. Wash down frl 11,185' - 11,187'. 2/15/06 Worked wash-over BHA onto fish. Dropped ball. PUH to 3-112" TOL. Shifted circ sub open. POOH. LD wash BHA. Appears wash pipe was over fish by ± 2.5'. RIH wi overshot BHA. Hit 5" TOL wi 20K. POOH to check OS guide. Inspected OS guide. OK. RIH wi OS BHA. Cont Rlli wi OS to 11,155'. Washed & jarred over fish frl 11,186' - 11,191'. Appeared to catch fish as seen with incr in pump press. Dropped ball. PUH to 3-1/2" TOL. Shifted circ sub open. Pumped dry job. POOH. 2/16/06 POOH wi OS BHA. LD fish. Recovered 1-11/16" mtr & 1.78" mill = 9.65 ft. LD OS. Rlli wi mtr & 2.5" tapered & string mill BHA. RIH to 10,300'. Cut & slip 100' drilling line. Tagged up @ 11,190'. Milling on 3-1/2" frl 11,185' - 11,200'. 2/17/06 Stopped milling @ 11,200'. POOH to 3-1/2" TOL. Opened circ sub. POOH. LD mtr/mills. Step mill worn on nose & steps 1 & 2. Little wear on Step 3 & string mill. RU for BOP test. Test BOP's & Hydril to 250/5,000 psi. Tstd accumulator. Tstd gas alarms. (Jim Regg of AOGCC waived witness of BOP test.) RD test assembly. RIH wi tapered mill BHA wlo a string mill. Washed down to 11,200'. Milled frl 11,200' - 11,202'. 2/18/06 Milled fr/11,202' - 11,501'. Pmpd gel sweep. Short trip 3-1/2" TOL. Tight @ 11,230' wI 1 OK - 20K over pull. CO 3-1/2" liner frIll ,50 l' - 11,554'. Cont clean out frill ,554' - 11,975'. 2/19/06 Clean out 3-1/2" liner frl 11,975' -11,988'. Mtr stalling @ 11,988'. Worked 20 min wi no progress. Dropped ball. Pmpd gel sweep. Opened circ sub. Circ sweep @ 4 BPM @ 2500 psi. Rev circ gel sweep @ 4 BPM @ 2,000 psi. POOH wi tapered mill BHA. LD mtr/mill. Rlli wi 5" scraper to 3-1/2" TOL. Slip & cut drilling line. Rev circ gel sweep @ 4.5 BPM @ 1600 psi. Check flow. Pmpd dry job. POOH wi 5" scraper. e e 4 2/20/06 POOH wI 5" scraper & LD. Rlli muleshoe on 2-1116" tbg (51 jts - 1,567). PU & RIH wI 5" retr pkr & tailpipe on DP. Set pkr @ 8,366'. (Well flwg up DP.) Not successful wI press test csg. Moved pkr to 8,356'. Retest failed. Moved pkr to 8,346'. Retest failed. Moved pkr to 8,360'. SIW. Monitored press. Mix 9.6 ppg salt pill. SIP = 250 psi. ReI pkr. Pmpd 48 bbls 9.6 ppg. Flow stopped. Set pkr. Press test csg to 1,900 psi. Lost 200 psi in 30 min. ReI pkr. Rev out 9.6 ppg brine to save in pits. Rlli wI pkr & tailpipe. Tagged @ 11,968'. Washed dwn to 11,988'. Rev circ. Spotted 22 bbls 10% HCL across the 3-112" & 5" liners. POOH 22 stands (MS @ 9934' & pkr @ 8368'.) Rev circ 1.5x DP vol 75 bbls to flow-back tank. Set pkr @ 8368'. Press TCA to 1000 psi. Pmp down DP to squeeze acid wI FIW @ 1.5 BPM @ 2650 psi. 2/21/06 Cont wI acid overflush (125 bbl) @ 1.5 BPM. SD. ISIP = 3,000 psi. 5 min = 1,500 psi, 10 min = 1,150 psi & 15 min = 1,000 psi. Bleed off 800 psi on TCA. Monitored flow- back on DP. SIW. Press was 350 psi in 1.5 hr wI pkr at 8,368'. Failed to get csg to test @ 1,900 psi. Opened well & monitored flow frl DP. Pmpd 10 bbls 9.6# brine down DP to stop flow. PUH to 7,440'. Had good press @ 1,900 psi for 15 min. Failed to get a test @ 7,904', 7,811' & 7,719'. Retested good @ 7,440'. POOH wI 5" pkr checking all connections (none loose). Inspected & LD 5" pkr. Pkr was good. POOH & LD 2-1/16" tbg & mule shoe. RIH wI new Baker 5" retr pkr. Set pkr @ 8,398'. Failed to get csg to test @ 1900 psi @ 8,398',8,294',8,201',8,108',8,016', 7,929' & 7,837' losing ±200 psi in 5 min. 2/22/06 Failed to get csg to test @ 1900 psi @ 7,743', 7,646', 7,552', 7,465', 7,434', 7,372', 7,280' & 7,189' loosing ±200 psi in 5 min. PUR looking for leak. PUR wI pkr & set @ 5703' near TOL. No test. Cont POOH. Blanked off bottom of pkr. Installed ported sub. RIH Set pkr 8,390'. Got good press test @ 1,900 psi & held 30 min. POOH LD DP. Found wash out in 2-7/8" DP causing leak. 2/23/06 Rlli wI 25 stands 3-112" DP & POOH LD. LD kelly, drive bushings, kelly valve, spinner & swivel. RU Weatherford tbg equip & JAM computers. RIH wI 2-7/8" completion string & 5" perm pkr. 2/24/06 Cont Rlli wI 2-718" tbg. MU hanger & landingjt. Drain stack. Land hanger. Screw in lock pins. Rev circ pkr fluid dn TCA @ 2 BPM @ 400 psi. RU WL. RIH & set N-test tool @ 8,391'. Press test tbg to 1500 psi for 15 min. Cont press up tbg to 4,000 psi to set pkr @ 8,344'. POOH wI N-test tool. Press test TCA to 1900 psi & hold 30 min. RD WL & landingjt. Set BPV. ND BOP's. RD BOP's from sub-base. LD riser. NU WHo Test flange, hanger seals & tree to 5000 psi. Completion Details: WLREG @ 8401', RN nipple @ 8,391',5" Perm Pkr @ 8,344' (SABL 30 - 24 9Cr), "R" nipples @ 8,335' & 321'. Ran 295 jts 2-7/8" 7.9# SLHT & 10 jts 2-7/8", 7.9#, RTS-6. Upweight -90k, downweight-80K. e e 5 2/25/06 RD rental equipment. Prep for backloading boat. RU BJ equip. Cleaning pits. Fin RU BJ. Blend acid. PJSM. Press test to 6,000 psi. Trouble shoot BJ computer. Pmpd 7,650 gal 10% HCL acid job wi foamed water for diversion: Stg Fluid Liquid, bbl Liq Rate, BPM N2 rate, scf A vg Press, psi 1 FIW 31 2 0 2300 2 Foam 19 0.4 963 2750 3 Acid 35.7 2 0 2778 4 Foam 19 0.4 963 3413 5 Acid 35.7 2 0 3216 6 Foam 28.6 0.4 963 3450 7 Acid 35.7 2 0 3500 8 Foam 33.3 0.4 963 1680 (lost N2) 9 FIW 75 2 0 2250 10 OverFlush 119 2 0 3117 SD pmpg. 5 min = 1,980 psi, 10 min = 1,666 psi & 15 min = 1,493 psi. Lost N2 unit during stg 8. (Lost prime.) RD BJ. 2/26/06 RD BJ. Flushed out acid tanks. Injected fluid from pits to disposal well. Rig released from A41A-11LN @ 1200 hrs 2-25-06. Put well on inj. Slowly incr rate. Inj 182 bbl @ 1,300 psi in 12.5 hrs. 2/27/06 Inj @ 557 BWIPD @ 1,400 psi. 2/28/06 Inj @ 654 BWIPD @ 1,850 psi. 3/1/06 Inj @ 949 BWIPD @ 2,450 psi. 3/2/06 Inj @ 1,118 BWIPD @ 2,800 psi. 3/3/06 Inj @ 1,094 BWIPD @ 2,850 psi. 3/5/06 Inj @ 1315 BWIPD @ 3300 psi. 3/6/06 Inj @ 1282 BWIPD @ 3350 psi. 3/7/06 Inj @ 1385 BWIPD @ 3600 psi. 3/8/06 Inj @ 1463 BWIPD @ 3600 psi. 3/9/06 Inj @ 1390 BWIPD @ 3600 psi. , . e e 6 3/10/06 Inj @ 1400 BWIPD @ 3600 psi. 3/11/06 Inj @ 1301 BWIPD @ 3600 psi. 3/12/06 Performed MIT for AOGCC. Press tested TCA to 2000 psi for 30 min wI no leak-off. Inj @ 1285 BWIPD @ 3600 psi. 3/13/06 Inj @ 1244 BWIPD @ 3600 psi. 3/14/06 Inj @ 1207 BWIPD @ 3600 psi. 3/15/06 Inj @ 1164 BWIPD @ 3600 psi. 3/16/06 Inj @ 1141 BWIPD @ 3600 psi. 3/17/06 Inj @ 1144 BWIPD @ 3600 psi. FINAL REPORT e ~,...,... ·.:~:·>'>.:·:o'''· ..... .. ." . . ." E:.NERGY ~~ * \0,&' \\q Current Comcletion MGS A41A-11LN WIW Cook Inlet, Alaska Leg 2, Conductor 12 API No.: 50-733-20179-03 Sidetracked: 8-6-95 A22-01 was P&A'd for the A41A-11 that was Spud in 3-7-86. 20" Conductor Csg @ 330' SurfCsg: 133/8",61#, K55. Set @ 1,990'. Cmt'd w/810 sk. Top Job w/170 sk. Intermediate Csg: 7", 26-29#, N80. Set @ 7,765'. Cmt'd w/824 sk. 26# : Surf - 1,659' 29# : 1,659 - 7,765' \>'tf"A~'!":::f'~ '-¥t.ðfl:1. ,<~'tr,; ',' ".\. r.. ') (\11"... i, ç.~. ~} t·:'~ L..L r.,. .J Liner: 5",18#, P110 STL. Set @ 10,743'. TaL @ 5,654'. TaL has isolation packer. Cmt'd w/ 560 sk. Liner: 3-1/2" 9.3# J55 BTC slotted. Set @ 12,045'. TaL @ 10,680'. TD:12,047' MD (10,046' TVD) e PLF 3-14-06 KB: 38' Water Depth: 73' MSL Tbg: 2-7/8" 7.9# L80 RTS-6 & Seal-Lock HT set @ 8,402' on Feb '06 9 Jts 2-7/8" 7.9# L80 RTS-6: Surf- 322' 2-7/8" Otis R Nipple (2.188" ID) @ 322' X-over 2-7/8" RTS6 Bx X SealLock HT Pin @ 323' 295 Jts 2-7/8" 7.9# L80 SealLock HTtbg X-over 2-7/8" SealLock HT Bx X RTS6 Pin @ 8,333' 2-7/8" Otis R Nipple (2.188" ID) @ 8,335' 8' Pup Jt 2-7/8" 7.9# L80 RTS-6 @ 8,336' Baker K anchor w/ seals L80 @ 8,343' 5" Baker SABL-3 Perm Pkr (30-24) 9Cr @ 8,344' 6' 3-%" MaE VAM Pin 9Cr @ 8,349' X-over 3.5" VAM Bx X 2-7/8" RTS-6 Pin @ 8,354' 6' Pup Jt 2-7/8" 7.9# L80 RTS-6 @ 8,355' 1 Jt 2-7/8" 7.9# L80 RTS-~ 8,361' 2-7/8" Otis RN Nipple (2.01" ID) @ 8,392' 8' Pup Jt 2-7/8" 7.9# L80 RTS-6 @ 8,393' WLREG @ 8,402' Isolated Peñs in 7" behind 5" liner: AS 6084'-6136' FL(1): 6574'-6638' FL(2): 6659'-6677' FP: 6746'-6772' FS(1): 6845'-6857' FS(2): 6870'-6881' GB(1): 7157'-7230' GB(2) 7251'-7289' HZ-HR: 10,530'-10,666' @ 6 spf Slotted Liner: HR-HN, HN-HK, HK-HI, HI-HE & HE-HC. e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Auber1@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: XTO Energy MGS A41 A-11 LN (Platform A) 02/23/06 Barney Phillips (XTO) Brad Rasch (IDA) None SKert Ôk:{DG t q5/ I \ q Packer Depth Pretest Initial 15Min. 30 Min. WelllA41A·11LN! Typelnj. S TVD 7,616' Tubing 0 0 0 IntervalT I P.T.D.1195-119 ! Type test I P Test psil 1904 Casing 1,900 1,900 1,900 P/F[ P Notes: OA Weill I Type Inj. I TVD Tubing IntervalT P.T.D.I I Type test I Test psil Casing P/F[ Notes: OA Well/ I Type Inj.1 ! TVD I Tubing I r I Intervall P.T.D.I I Type test I I Test psi! Casing I I I P/FI Notes: OA I Weill I Type Inj. TVD I I Tubing I I Interval I P.T.D.I I Type test I Test psil I Casing I P/FI Notes: I OA I I Weill I Type Inj. I TVD I Tubing Interval I P.T.D·I I Type test I I Test psi I Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waist G = Gas I = Industrial Waistewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test dUring Workover 0= Other (describe in notes) 2006-0223_MIT _MGS_A41 A-111 LN.xls o ENERGY MGS A11-13RD2 WIW Cook Inlet, Alaska Leg 2, Conductor 14 API No.: 50-733-20007-01 Spud Orig well A 11-13: 4-1-67 Sidetrack: 5-11-81 e Surf Gsg:10 3/4", 40.5#, J55 @ 1,776'. Gmt wi 1,150 sx + 600 sx Top Job. Intermediate Gsg: 7",26-29#, @ 8,778'. 0- ± 2,000' : 26#, N80, BTG. ± 2,000 - 8,778' : 29#, S95, L TG_ Gmt wi 800 sx. Bad spot in 7" Csg @ 8,365' (57% worn). Kinley Caliper Jan '06. Liner: 5",18#, N80, FL4S. Set @ 10,184'. TOL @ 8,476'. Gmt wi 345 sx. Fill & Fish (3 magnets & parted Gail tbg) (3-18-90). GO fill to 10,010' Jan '06. PBTD: 10,010' MD (9,548' TVD) TD: 10,200' MD (9,715' TVD) e PLF 2-23-06 KB: 38' Water Depth: 73' MSL ~./\\f\ \0\ Tbg: 2-7/8" 7.9# L80 RTS-6 @ 8,499' Set on 1-30-06 2-7/8" Otis R Nipple (2.188" ID) @ 290' .. ·260 jts 2-7/8" 7.9# L80 RTS-6 tbg 2-7/8" Otis R Nipple (2.188" ID) @ 8,406' 6' Pup Jt 2-7/8" 7.9# L80 RTS-6 @ 8,407' X-Over 2-7/8" RTS-6 Box X 8rd Pin @ 8,413' Baker (80-32) E anchor wi seals L80 @ 8,414' 7" Baker SAB-3 Perm PKR (84-32) 9Gr @ 8,415' 5' 4-W' MaE 12.6# 9Gr @ 8,420' X-over 4.5" VAM Bx X 2-7/8" RTS-6 Pin @ 8,425' 4' Pup Jt 2-7/8" 7.9# L80 RTS-6 @ 8,426' 2 jts 2-7/8" 7.9# L80 RTS-6 2-7/8" Otis RN Nipple (2.01" fD) @ 8,493' 4' Pup Jt 2-7/8" 7.9# L80 RTS-6 @ 8,498' WLREG @ 8,499' HK-HN: 9,505 - 9,546' HK-HN: 9,552 - 9,639' HN-HR: 9,650 - 9,710' HN-HR: 9,734 - 9,792' HR-HZ: 9,853 - 9,902' Re: BOP Inlet XTOA 1-31-06 e e Pitjj 1'15 - 1\9 Sub,icet: Rc: BOP Inlet XTOA 1-31-06 l From: James Regg <~im_rcgg@admin.state.ak.us>~¿¿Cl \ ~'31 ,Ol, Date: TlIe, 31 Jan 200614:18:08 -()<)oo 1 I To: Alaska _Drilling@jxtocnergy.com CC: aogcc_".prudho~ _ bay@admin.state,ak.us, bob _ fleckcnstcin@admin.statc.a.k.llS Brad - I am waiving our witness of this BOPE test on MGS A41A-11LN. Please send us a report after the test as normal. Thank you for the advance notice. Jim Regg AOGCC Inspection Supervisor !i:~?:§.~?:_I:J!::~~~~I?:9~~t:_c:J"'~E?!::gY:c:.:C?I11 wro t e : Gentlemen, Presently rigging up on well A41A -llLN and should be killing the well late this afternoon. Then nippling up the BOPE. If things go well, we will be testing BOPE on Wednesday 2-1-06. I will let you know if we have any problems or delays. Regards, Brad Rasch Platform A 907-776-2500 (.;,;r-L¡!:"~/~\í:r) \." t !)î;;.;)(rt;,; '; , 1 of 1 1/31/20062: 18 PM e e ~ ïr IM"U' I? @ UL~I J: (ill ~ f"? I",: !, q....", : !·Ir : 'u i;-;; n 11\' ' ¡' iUyit, ,,1" /' ,- " . 'I '1 ¡ ~ .' fL ~ '\' " n 1.1..,\, II , k '. lJ"1J l::=:J U U FRANK H. MURKOWSKI, GOVERNOR A1tASIiA. OILAlO) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Figel Engineering Manager XTO Energy Inc. 200 N. Loraine, Suite 800 Midland, Texas 79701 \q'1'..-\\Q Re: MGS A41A-IILN Sundry Number: 305-383 ~(;AND~EU {, t, Dear Mr. Figel: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this/~day of December, 2005 Enc!. e e RECEIVED ~TO DEC 14 2005 ~ kRGY Alaska Oil & Gas Cons. Commission Anchorage XTO Energy Inc. 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) December 13, 2005 Alaska Oil and Gas Conservation Commission Attn: Mr. John Norman 333 West 7tl1 Ave., Suite 100 Anchorage, Alaska 99501 RE: Request for Sundry Approval to Repair & Stimulate Water Injection MGS Well A41A-IILN. Dear Mr. Norman: XTO Energy, Inc. hereby submits its Application for Sundry Approval for well A41A-llLN on Platform A, in the Middle Ground Shoal Field of Cook Inlet. The objectives of this workover are to repair the pressure communication on the injection tubing annulus & retrieve a coil tubing fish that was lost in the top of the slotted production liner. A new injection packer & tubing string will be installed followed with an acid stimulation treatment. Please find attached the following information for your files: 1. Form 10-403 Application for Sundry Approval 2. Job Procedure 3. Present Wellbore Schematic 4. Proposed Wellbore Schematic Please contact me with any questions @ 432-620-6743. Sincerely, jJJ c! Y Paul L. Figel Engineering Manager Cc: Scott Griffith Tim Smith · /~ RECEIVEIJ STATE OF ALASKA tA ...""~ AOILANDGASCONSERVAT1ONCOM~ 'OI\I-\DEC 14 2005 ~ APPLICATION FOR SUNDRY APPROV At " n" jt. G.' Cans. commission 20 AAC 25280 AIAba ~I ~ ....... - r-'"' - 1. Type of Request Abandon 0 Suspend U Operational shutdown U Perforate U Waiver U ~.her 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 PuR Tubing 0 Perforate New Pool 0 Re-enter Suspended WeD 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: XTO Energy Inc. Development 0 Exploratory 0 195-119 V 3. Address: Stratigraphic 0 Service 0 6. API Number: vi 200 N. Loraine, Suite 800, Midland, Texas 79701 50-733-20179-03 7. KB Elevation (ft): 9. Well Name and Number: 38' A41A-11lN 8. Property Designation: 10. FieldlPooIs(s): "A", leg 2, Cond 12, 1677' FSl & 367' FEL, S11,TSN,R13W,S.M. Middle Ground Shoal 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): rota! Depth 1VD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12,047' 10,046' 12,045' 10,045' 10,935' Casing Length Size MD TVD Burst Collapse structural Conductor Surface 1990' 13-318" 1990' 1934' 3090' 1540' Intennediate 7765 ¡- 7765' 7151' 7240' 5410' Liner 1 5089' 5" 10743' 9196' 13940' 13450' Slotted Liner 2 1365' 3-112" 12045' 10045' Slotted Slotted Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: ITubing Grade: Tubing MD (ft): 10530 - 12045 9044 - 10045 2-7/fr & 2-318" LBO 8515' Packers and SSSV Type: Baker DB pkr Packers and SSSV MD (ft): 8430' 12. Attachments: Description Summaty of b!J 13. WeD Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well status after proposed work: Commencing Operations: 1/1612006 011 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Figel Printed Na~ Paul Figel TItle Engineering Manager Signature 'U,1. ~f Phone 4320682-8873 Date 12/1312005 0 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: (305- '?;g ~ Plug Integrity 0 BOP Test .~ Mechanical Integrity Test ~ location Clearance 0 other: JDi' APPROVED BY 11~K ¿ - ...,. 'j I/o COMMI$SIONER THE COMMISSION Date: <. ...._. Form ~ R~ 07l2ook., "'" , ß .5 - it In Duplicate - OR\G\NAl -- \f\ - \0. ~ R ~f1 15 /Y'e- ;[tg e e XTO ENERGY INC. MGS A41A-IILN WEST FLANK HEMLOCK, COOK INLET, ALASKA REPAIR PRESS COMMUNICATION & STIMULATION PROCEDURE WELL DATA: SURFACE CASING: 13-3/8",61#, K55. Set@ 1,990'. Cmt wi 810 sx + 170 sx Top Job. INTERMEDIATE CASING: 7",26 - 29#, N80. Set @ 7,765'. Cmt wi 824 sx. Surf -1,659': 26# 1,659 -7,765': 29# DRILLING LINER: 5", 18#, PlIO, STL. TOL @ 5,654'. Set @ 10,743'. Cmt wi 560 sx. PRODUCTION LINER: 3-1/2",9.3#, J55, BTC. TOL @ 10,680'. Set @ 12,045'. SLOTTED. PBTD: 12,047' MD. CURRENT TBG: 2-7/8",6.5#, L80, 8rd EVE: Surface - 5,520'. 2-3/8",4.7#, L80, 8rd EVE: 5,520 - 8,515'. PACKER: 5" Permanent Baker DB Packer @ 8,430'. GLM's wi Dummies: 2-7/8" GLM @ 1947', 3726', 5096' & 2-3/8" @ 6208', 7094', 7734', 8346'. PERFS & SLOTS: Perfs in 5" Liner in HZ - HR: 10,530 - 10,666' Slotted from 10,743 -12,045': HR-HN, HN-HK, HK-HI, HI-HE & HE-HC. BHST: 160 Deg F BHP: 3,200 psi HOLE DEVIATION: Max 53 Deg @ 9,738' SMALLEST ID: 2-3/8" XN Nipple @ 8,482' (1.791" ill) FISH: Baker Motor & Mi111.78" OD x 10.5' L @ 10,935'. CURRENT INJECTION: 496 BWIPD @ 3,600 psi WHP & 4,000 psi on TCA. OBJECTIVE: Retrieve fish, acidize formation & replace the tbg and packer. NOTES: · AFE # 507695 · 210 bbl Diesel is on the tbg backside & will be circ back into the production header. · APRS 2-3/8" jet cutter requires an ID > 1.82". · WL tagged fill @ 10,784' on 9-9-05 wi 1.75" gauge ring. Procedure 12-13-05 e XTO Energy Inc. MGS A41A-IILN COOK INLET, ALASKA Materials Rqd: 10,000 gal 10% HCL acid to contain µer 1,000 gal: · 2 gpt CI-25 Corrosion Inhibitor · 10 gpt Ferrotrol300L Iron Control · 2 gpt NE-118 Non-Emulsifier · 100 gal Foamer FA W (BJ) · 4,000 gal N2 · 2,000 lbs Soda Ash (MI) · 300 lbs Flo-Visc (MI) · 40 gal 99VD-049 Corrosion Inhibitor (Nalco) · 30 gal EC6065A Oxygen Scavenger (Nalco) · 250 BBL PTS Flowback Tank · Plastic lined frac tank for Acid Job (± 250 bbl Capacity) Procedure 12-13-05 e 2 e e 3 XTO Energy Inc. MGS A41A-IILN COOK INLET, ALASKA PROCEDURE: 1. SD injection 1 week prior to workover. MIRU derrick. 2. MIRU XTO Slickline Unit. Press test lubricator to 1,000 psi. RIH wi 1.85" gauge ring. Tag up on XN nipple @ 8,482'. POOH. RIH wi pulling tool to GLM #7 & pull the dummy valve. RD SL. 3. RU the mud pump on tbg annulus and lay a flowline from the WH to the production header. Rev out the 210 bbl diesel from the TCA into the header system wi FIW & a 20 bbl gel sweep until rtns are clean. SD & monitor the well for 30 minutes. Ifwell is dead, proceed to Step #4. If well is live, based upon the SIWHP, prepare 300 bbl of weighted CaCh brine water. Reverse circ brine wtr to kill the well. SWI & monitor press for 30 min. 4. Set BPV. ND tree and NU riser & BOP's. Set 2 way check valve and press test BOP's to 250 psi & 5,000 psi. 5. MI 5,500' 2-7/8" 10.4# X95 SLHT DP, 12 ea 3-1/8" DC, 6000' 3-1/2" 15.5# S135 DP, & 1800' of 2-1/16" tbg wi the necessary x-overs. 6. RU Weatherford tong services. PU max of 83,000# (80% of 140,000#) over hook-load to pull seals from the packer. Consult the Midland office before exceeding this limit. Continaency Plan If Seals Fail to Pull: a) RU APRS WL. RIH wI 1-13/16" jet cutter & cut the tbg as close the X nipple @ 8,391' as possible. b) POOH & LD 2-7/8" & 2-3/8" tbg while checking for NORM. c) RIH wI Baker Overshot wI 2-3/8" grapples & jars BHA on 9 ea 3-1/8" DC & 2-7/8" DP. d) Est string weight before engaging fish. Attempt to jar seals from packer. e) Circ bottoms up before POOH wI fish. 7. POOH & LD 2-7/8" & 2-3/8" tbg while checking for NORM. Send tbg in to be sold for scrap. 8. MU 4-1/8" Baker Pkr milling BHA on 3-1/8" DC, 2-7/8" DP. RIH to top of pkr. Est string weight. Mill pkr per Baker packer milling procedures. After the pkr falls, circ bottoms up. Push pkr to TOL @ 10,680'. POOH wi mill. RIH wi 2-5/16" spear & grapple to retrieve pkr. POOH slowly wi pkr. 9. PU 2-7/8" Bowen Series "150" Overshot wi 1-11/16" grapples. RIH on 10 jts 2-1/16" tbg, jars, 9 ea 3-1/8" DC, 5,200' of 2-7/8" DP & 3-1/2" DP. Engage fish (motor/mill) @ 10,935'. Attempt to work fish free. Contact Midland if unsuccessful before resorting to pushing fish to PBTD. LD OS. 10. MU Baker clean out assembly: 2.875" mill, 2.875" string mill, motor, ±1,450' of2-1/16" tbg, Jars, 9 ea 3-1/8" DC, 5,200' of2-7/8" DP & 3-112" DP. RIH wi BHA to PBTD @ 12,045'. Circ 20 bbl gel pill (3 #/bbl Flo-Visc) to surface. POOH. LD BHA. Stand back all DP & 2-1/16" tbg. 11. RIH wi bit & scraper for 5" 18# casing. Make scraper run to 3-1/2" TOL @ 10,680'. Reverse circ a 20 bbl gel pill. POOH. LD bit & scraper. Procedure 12-13-05 e e 4 XTO Energy Inc. MGS A41A-IILN COOK INLET, ALASKA 12. PU 5" Baker Retrievamatic packer wi 1,600' of2-lI16" tbg for tailpipe. RIH wi pkr. Set packer @ ±8,350'. Press test backside to 1,900 psi. Monitor for 30 min. Rel pkr. Contact the Midland office ifthe press test fails. Cont RIH to land tailpipe @ PBTD @ 12,045'. 13. MIRU BJ acid equipment, PTS flowback tank & lined acid tank. Blend 10,000 gal 10% HCL. Install a press transducer on the tbg annulus. Put 1,000# soda ash in the PTS tank. Tie in the wellhead to the PTS tank with XTO 2" flowback iron. Press test lines to 1,000 psi. Est circ down the DP wi FIW. Pickle the DP with 500 gall 0% HCL acid @ 2 BPM. Under displace the acid bv 6 bbl from the DP capacity. Using the mud pump, reverse out acid to the PTS tank wi FIW @ 2 BPM. Pump spent acid into disposal well A44-11 & record all volumes injected. 14. Spot & balance 15 bbll0% HCL from 12,045 -10,500'. PUH 20 stands wi EOT above upper perf (pkr @ ±8,650'). Let acid soak for 30 min. 15. RIH wi 20 stands back to 12,045'. Reverse circ acid back to the PTS tank @ 2-3 BPM. 16. Repeat Step #14. 17. RO 1.5x DP volume (±75 bbl) to clear pkr of acid. Set pkr @±8,650'. Put 1,000 psi on backside. 18. BJ to re-test lines to 6,000 psi. MAX Press for job is 5,000 psi. Overflush acid with 50 bbl FIW. SD. Obtain 5, 10 & 15 min reading. Bleed-offpress. Rel pkr. POOH. LD DP, tbg & pkr. Rel BJ crew but leave pump & lines rigged up for acid sqz in Step #24. 19. MI 15 jts 2-7/8" 7.9# L80 RTS-6 + 8,400' 2-7/8" 7.9# L80 Seal-Lock HT thrd tbg (incl4% excess). 20. RU Weatherford Jam monitor system. RIH wi Baker 5" SB-3 Chrome Perm Pkr as follows: Item Length, ft Top Bottom 2-7/8" 7.9# L80 RTS-6 Tbg 330 0 330 2-7/8" Otis R Nipple (2.188" ID) RTS-6 9Cr 1 330 331 X-Over 2-7/8" RTS-6 Box X Seal-Lock HT Pin 7.9# 9Cr 1 331 332 2-7/8" 7.9# L80 Seal-Lock HT Tbg 8,008 332 8,340 X-Over 2-7/8" Seal-Lock HT Box X RTS-6 Pin 7.9# 9Cr 1 8,340 8,341 2-7/8" Otis R Nipple (2.188" ID) RTS-6 9Cr 1 8,341 8,342 6' Pup Jt, 2-7/8" 7.9# L80 RTS-6 6 8,342 8,348 X-Over 2-7/8" RTS-6 Box X 8rd EUE Pin 1 8,348 8,349 Anchor KBH-22 w/ Seals 8rd Box L80 1 8,349 8,350 5" Baker SABL-3 Permanent Packer (30-24) 9Cr 4 8,350 8,354 6' Millout Extension (3-1/2" OD) VAM Pin 9Cr 6 8,354 8,360 X-Over 3-1/2" VAM Box X 2-7/8" 7.9# RTS-6 Pin 9Cr 1 8,360 8,361 1 Jt, 2-7/8" 7.9# L80 RTS-6 32 8,361 8,393 2-7/8" RN Nipple, 2-7/8" (2.01" ID) RTS-6 9Cr 1 8,393 8,394 6' Pup Jt, 2-7/8" 7.9# L80 RTS-6 6 8,394 8,400 WLREG 1 8,400 8,401 Procedure 12-13-05 XTO Energy Inc. MGS A41A-llLN COOK INLET, ALASKA 5 21. Prior to setting the packer, pump 250 bbl packer fluid containing 10 gal! 1 00 bbl EC6065A Oxygen Scavenger & 15 gal!l 00 bbl 99VD049 Corrosion Inhibitor @ 3 BPM. 22. RU Slickline. Press test lubricator to 4,000 psi. RIH wi "N" test tool plug & seat on RN nipple @ 8,393'. Press test tbg to l,OOO psi for 15 min. Monitor falloff. Cont to press up to ±3,500 psi to set pkr. Hold a 4,000 psi press test for 15 min. Bleed off the press. POOH wi "N" test tool. RD SL. 23. Set BPV. ND BOP's & riser. NU WH wi new SS tbg hanger. Pull BPV. Set 2-way check. Test WH to 5,000 psi. Pu1l2-way check. 24. RU BJ N2 Unit. Cool down N2 unit. Press test line to 6,000 psi. RU BJ liquid line & test to 6,000 psi. MAX Press for job is 5,000 psi. Conduct pre-job safety & operations mtg wi all personnel noting hazards of acid, N2 & high press. Perform staged acid sqz job wi the following schedule: . LIQUID LIQUiD FOAM BH FOAM LlQ RATE N2 RATE N2 N2 FOAM STG FLUID GAL BBL % RATE-BPM BPM SCF/M SCF GAL BBL MIN . FIW 1,300 31.0 - 2.0 2.0 - - - 31 15.5 2 Foamed WTR 800 19.0 70 2.0 0.6 1,540 48,889 525 63 31.7 3 Acid 1,500 35.7 - 2.0 2.0 - - - 36 17.9 4 Foamed WTR 800 19.0 70 2.0 0.6 1,540 48,889 525 63 31.7 5 Acid 1,500 35.7 - 2.0 2.0 - - - 36 17.9 6 Foamed WTR 1,200 28.6 70 2.0 0.6 1,540 73,333 788 95 47.6 7 Acid 1,500 35.7 - 2.0 2.0 - - - 36 17.9 8 Foamed WTR 1 ,400 33.3 70 2.0 0.6 1,540 85,556 919 111 55.6 9 Acid 1,500 35.7 - 2.0 2.0 - - - 36 17.9 10 Foamed WTR 1,500 35.7 70 2.0 0.6 1,540 91,667 984 119 59.5 11 Acid 1,500 35.7 - 2.0 2.0 - - - 36 17.9 12 Over-Flush 5,000 119.0 - 2.0 2.0 - - - 119 59.5 ....... 19;_ 333 ç¡..... ...'. · N2 Volume Factor @ 125 Deg F @ 3500 psi BHP = 1100 scfl bbl space · All water stages 1-10 consists of plain FIW + 10 gpt FA W F oamer 25. SD pump. Obtain 5, 10, 15 min reading. RD BJ. Flush out acid tank wi FIW. 26. Notify the AOGCC 48 hours prior to the MIT. 27. Perform MIT on the tbg annulus with an AOGCC witness. With the 5" Packer set @ 8,350' MD, press test the tbg annulus to 1,900 psi. (7,616' TVD x 0.25 = 1,904 psi) & hold for 30 minutes. 28. Put well on injection with a target rate of 700 BPD. n 9.~ yJ c.-t òI. ... Paul Figel, Engineering Manager Kyle Hammond, VP Operations Procedure 12-13-05 e e " .,.~ ;[!R MGS A41A-11LN WIW Cook Inlet, Alaska Leg 2, Conductor 12 API No.: 50-733-20179-03 Sidetracked: 8-6-95 A22-01 was P&A'd for the A41A-11 that was Spud in 3-7-86. 20" Conductor Csg @ 330' Surf Csg: 133/8",61#, K55. Set@ 1,990'. Cmt'dw/810sk. Top Job w/ 170 sk. Intermediate Csg: 7", 26-29#, N80. Set @ 7,765'. Cmt'd w/ 824 sk. 26# : Surf - 1,659' 29# : 1,659 - 7,765' Liner: 5",18#, P110 STL. Set @ 10,743'. TaL @ 5,654'. TaL has isolation packer. Cmt'd w/ 560 sk. WL Tagged Fill @ 10,784' (9-9-05) Liner: 3-1/2" 9.3# J55 BTC slotted. Set @ 12,045'. TaL @ 10,680'. TD:12,047' MD (10,046' TVD) e Present Completion . . . . . ....... . ~ I I I I e PLF 12-8-05 KB: 35' Water Depth: 73' MSL Tbg: 2-7/8" 6.5# L80 8rd EUE (used) & 2-3/8" 4.7# L80 8rd EUE (new) X-over 2-7/8" x 2-3/8" @ 5,520' Pkr & Tbg Set on 10-21-95. "X" Nipple (2.313" ID) @ 340' GLM MD TVD GLV 1 1947' 1895' Dummy 2 3726' 3519' Dummy 3 5096' 4724' Dummy 4 6208' 5709' Dummy 5 7094' 6521' Dummy 6 7734' 7122' Dummy 7 8346' 7612' Dummy (3ea 2-7/8" D-SO & 4ea 2-3/8" U-SO GLM's) 1 Jt 2-3/8" 4.7# L80 8rd EUE X Nipple (1.875" ID) @ 8,391' 1 Jt 2-3/8" 4.7# L80 8rd EUE 5" Baker DB Permanent Packer @ 8,430' 15' Sealbore Extension w/15' seals inside 1 Jt 2-3/8" 4.7# L80 8rd EUE 2-3/8" XN Nipple (1.791" ID) @ 8,482' 1 Jt 2-3/8" 4.7# L80 8rd EUE WLREG @ 8,515' Isolated Perfs in 7" behind 5" liner: AS 6084'-6136' FL(1): 6574'-6638' FL(2): 6659'-6677' FP: 6746'-6772' FS(1): 6845'-6857' FS(2): 6870'-6881' GB(1): 7157'-7230' GB(2) 7251'-7289' HZ-HR: 10,530'-10,666' @ 6 spf Fish @ 10,935' Consists of GS Fishing neck, Baker Mach 1 mtr, X-over & Baker junk mill. Length = 10.5' w/ 1.78" max OD. Lost in hole 4-27-01 Slotted Liner: HR-HN, HN-HK, HK-HI, HI-HE & HE-HC. ;[tg MGS A41A-11LN WIW Cook Inlet, Alaska Leg 2, Conductor 12 API No.: 50-733-20179-03 Sidetracked: 8-6-95 A22-01 was P&A'd for the A41A-11 that was Spud in 3-7-86. 20" Conductor Csg @ 330' Surf Csg: 133/8",61#, K55. Set @ 1,990'. Cmt'd w/ 810 sk. Top Job w/ 170 sk. Intermediate Csg: 7", 26-29#, N80. Set@ 7,765'. Cmt'd w/ 824 sk. 26# : Surf - 1,659' 29#: 1,659 - 7,765' Liner: 5", 18#, P11 0 STL. Set @ 10,743'. TOL @ 5,654'. TOL has isolation packer. Cmt'd w/ 560 sk. Liner: 3-1/2" 9.3# J55 BTC slotted. Set @ 12,045'. TOL @ 10,680'. TD:12,047' MD (10,046' TVD) e Proposed ComDletion I I I I I I I I e PLF 12-13-05 KB: 35' Water Depth: 73' MSL Tbg: 2-7/8" 7.9# L80 RTS-6 & Seal-Lock HT set @ 8,501' on 2-7/8" 7.9# L80 RTS-6 Tbg: Surf - 330' 2-7/8" Otis R Nipple (2.188" 10) @ 330' X-over 2-7/8" RTS6 Bx X Seal Lock HT Pin @ 331' ±267 jts 2-7/8" 7.9# L80 Seal Lock HT tbg X-over 2-7/8" Seal Lock HT Bx X RTS6 Pin @ 8,340' 2-7/8" Otis R Nipple (2.188" 10) @ 8,341' 6' Pup Jt 2-7/8" 7.9# L80 RTS-6 @ 8,342' X-Over 2-7/8" RTS-6 Box X 8rd Pin @ 8,348' Baker E anchor w/ seals L80 @ 8,349' 5" Baker SABL-3 Perm Pkr (30-24) 9Cr @ 8,350' 6' 3-%" MOE VAM Pin 9Cr @ 8,354' X-over 3.5" VAM Bx X 2-7/8" RTS-6 Pin @ 8,360' 1 jt 2-7/8" 7.9# L80 RTS-6 @ 8,361' 2-7/8" Otis RN Nipple (2.01" 10) @ 8,393' 6' Pup Jt 2-7/8" 7.9# L80 RTS-6 @ 8,394' WLREG @ 8,401' Isolated Perfs in 7" behind 5" liner: AS 6084'-6136' FL(1): 6574'-6638' FL(2): 6659'-6677' FP: 6746'-6772' FS(1): 6845'-6857' FS(2): 6870'-6881' GB(1): 7157'-7230' GB(2) 7251'-7289' HZ-HR: 10,530'-10,666' @ 6 spf Slotted Liner: HR-HN, HN-HK, HK-HI, HI-HE & HE-HC. 1000 900 800 100 C Q.. 600 ~ 500 400 300 200 100 0 5/1/2005 6/1/2005 7/1/2005 Note the 350 psi difference is due to of diesel 01'1 the TCA &, 8.5 ppg water 8/1/2005 9/1/2005 1011/2005 11/1/2005 Ann Press, , 5000 4000 3000 2000 1000 o (~ ,,~ i ~ I II: :[ : ]11.1 i.· ~I..:ìi I : II! : I, \,\..,1 i U ) f";1 :-.~ !.'.'¡¡\.\~.". I:.I! ! u \, ,i , ~ \ II: !U U L.;=:i ) /i.i"~,~.\. .. Û· . ¡I i ; \ U!.';i [. I, \ I I I f ,/ 1 l FRANK H. MURKOWSKI, GOVERNOR A.~A~1iA. OIL AND GAS CONSERVATION COMMISSION 333 W. ¡rH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Figel Engineering Manager XTO Energy Inc. 200 N. Loraine, Suite 800 Midland, Texas 79701 \~6~\ \ 0, Re: MGS A41A-11N Sundry Number: 305-286 SC;ANNED NO'J 0 2, 2005 Dear Mr. Figel: Enclosed, unapproved, is the Application for Sundry Approval relating to the above referenced well. As communicated to you via email, at this time a sundry application is not appropriate. Please contact Tom Maunder, PE at (907) 793-1250 with any questions Sincerely, DATED iliisJt day of October, 2005 Encl. .1. V ( i 0 ( V <> ill ; <> V ì'l\A 4 J ;: IHrt u ð \j ;: ATU ~N~J:<.(';Y-nll)LAN1) I2:JUV~ -- 1. Type of Request ) STATE OF ALASKA -\ ALASKA OIL AND GAS CONSERVATION COMMIS....JN APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class~ Development 0 Stratigraphic 0 I~~"',,~~~¡. 'r"""~~J 1-'~:~i '\r.~~ ~\:I ~~ ~~ I.'....~~ö 't ':,114 t.i;7~.f("",-w~,,-~'""" .....~ J\'~ . ~ ,~. ,~~,~ \i,,~,~,~:ø ~~(.i'~ ''<!f! ~"'.I" Abandon U Alter casing 0 Change approved program 0 2. Operator Name~ XTO Energy lne. 3. Address: 200 N. Loraine, Suite 800, Midlal1d, Texas 79701 7. KB EIeva1ion (ft): 9. Well Name and Number: 38' A41A-11LN 8- Property Designation; 10. FleldlPools(s): "A", Leg 2, Cond 12, 16T1' FSL $. 387' FEL, $11 ,T8N,R1SW,$.M. Middh~1 Ground Shoal '1_ PRESENT WELL CONDITION SUMMARY Total Depth MD (ft)~ Total Depth TVD (ft): Effecti\le Depth MO (ft)~ Effecti\lSl Depth lVD (ft), 12,047' 10,046' 12,045' 1Q,045' Cat:lng Length Size YD StruCtUral Suspend U Repair well D Pull TubingO I(ID'I'O, ",¡,. ')1 \\·i\ . ('¡fie;):, ....', 0 I i '0.1 l I G,II.'. Perforate [J Waiver - Other I.!I Stimulate 0 Tlm~~~ 3:'"r" ~~Jt, {::&.i~fft~g~;"~ Re-en1er Suspended Well 5. Permit to Drill ExplaratolY 0 195-119 '" Ii] 6. API N bar= 50-7S 20119HDS ~ Service ConductOt Surface 1990' . 0 . QJt. (¿~, \ S~.~ ' N..,\t~~1 ,~IUg$ (m~r~);\ ~ 1oRk~~ . 10,935' Burst Collap:¡e 13-318" 199(\ 771;5' 3090' 1240' 13940' Slotted 1540' 5410' 5R 1934' 7151' 9198' 10045' Tubing Grada~ IS" LBO paë1 and SSSV MD (ft): , ~: . '\ \..... rell Class - propooed work; ~XPloratOry 0 Development " ~'. ~ 5. Well Status after propose(t work; . - 011 0 Gas 0 Plugged 0 o ,'WAG 0 GINJ 0 WlNJ 0 13450' Sloited Tubing MD (ft); $615' Intermediate 7165' Uner 1 5089' " . Slotted ünef 2 1365' 3·1/2" '~.Perlollbtlon Depth MD - (ft)~ Petforation Qep1h rvn4): '0530 -12045 9044 -10045 ,0' . ¡'.cIœr.J Md SssVTYi1e: Baker DB pkr ,,\ " \ ~' ~ - 12. Attachments: Description Sul\'mary " ~roposal Detailed Operatitl~$ Program 0 BoP? :ketc'\ 14. Estimated Date for Commencing Oparatlon8: V 16, verbal Approval: ,- )8 1 Commission Representative: \. 17. I heÇ!by certify that tha foregoing i5 tnJe ~ PtinllKf Nam. n Paul RgeI SIQna\uno 'r'a-i;;1. ~ 7" 8430' o SerVice rn Abandoned WDSPL o o rrect to the best of my knowledge. Contact TItle Englneeñng Manager Phone 432-682-8813 Date COMMISSION use ONLY Paul Figel 9/2612005 missIon so that a rapmsentative may witness Suñd.y Numbe~~05 - d~ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 i'..\~f'.~~\. \D\~..<>'tR~~\)\{>'W1 ~-\~~~\.,,~ ,~"»?\~)) (" ~~, ~<::o~~"J 'co, ~h. ,-0<:' IQ1Jw".".>\tc..\\-.JE' G?~tc:NQ \ ~\\tJ Oltlel': è) 0..,\ - 1:\. ~ \c.\'- l Ç'\O ~.'<.. COMMISSIONER APFJROVED BY THE COMMISSION Oate~ / Fotm 10-403 Revi,*, 0712005 ORIGINAL RBDMS 8Ft 0 CT 3 1 2005 Submit in Dyplioata RECEIVED STATE OF ALASKA ALA )\ Oil AND GAS CONSERVATION COMfv. )ION SEP 2 8 2005 APPLICATION FOR SUNDRY APPROVALAlaskaOiI&G C C. i... 20 AAC 25.280 . . as on·~/9,ømlslOn 1 . Type of Request: Abandon U Suspend U Operational shutdown U Perforate U Waive~Oraß' Other l:J Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit to D' Number: XTO Energy Inc. 3. Address: 200 N. Loraine, Suite 800, Midland, Texas 79701 7. KB Elevation (ft): 38' Development D Stratigraphic 0 Exploratory D Service 0 9. Well Name and Number: A41 A-11 LN 8. Property Designation: 10. Field/Pools(s): "A", Leg 2, Cond 12, 1677' FSL & 367' FEL, S11 ,T8N,R13W,S.M. Middle Ground Shoal 11. PRESENT WELL CONDITION SUMMA Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth Plugs (measured): Junk (measured): 12,047' 10,046' 12,045' 10,045' 10,935' Length Size MD TVD Burst Collapse Casing Structural Conductor Surface 1990' Intermediate 7765' Liner 1 5089' Slotted Liner 2 1365' Perforation Depth MD (ft): 10530 - 12045 Packers and SSSV Type: 13-3/8 " 1990' 1934' 3090' 1540' 7" 7151' ~ 7240' 5410' 5" ':'-'J~r 13940' 13450' 3-1/2" Slotted Slotted Perforation Depth TVD (ft): I\) l «;' Æ2fVJ Tubing MD (ft): 9044 - 10045 2-3/8" . 8515' Baker DB pkr Packers and SS · (ft): ' 8430' 12. Attachments: Description Summary of Proposal Detailed Operations Program D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true an correct to the best of my knowledge. Contact Paul Figel Printed Name Paul Figel Title Engineering Manager Signature ~ ~~. :¡~f' Phone 432-682-8873 Date I COMMISSION USE ONLY 13. Well Class after proposed work: Exploratory D Development D Service 0 15. Well Status after proposed work: 9/6/05 Oil D Gas D Plugged D Abandoned D WAG D GINJ D WINJ 0 WDSPL D 9/26/05 Subsequent Fo Sundry Number: ?1.:)5- tÂ.,<{. (0 Conditions of approval: Notify Co ission so that a representative may witness Plug Integrity D Mechanical Integrity Test D Location Clearance D Other: Approved by: ... ._-----..... ---I \ FOon~~:;~~~ COMMISSIONER APPROVED BY THE COMMISSION Date: ORIGINAL Submit in Duplicate ) ) RECEIVED SEP 2 8 2005 Alalka Oil & G I' Con.. Co '. AnChorage mtn/SS10n ~TO ~kRGY XTO Energy Inc. 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) September 26, 2005 Alaska Oil and Gas Conservation Commission Attn: Mr. John Norman 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Request for Sundry Approval to Continue Injection Operations on MGS Well A41A-11LN. Dear Mr. Norman: XTO Energy, Inc. hereby submits its Application for Sundry Approval to continue injection operations on well A41A-11LN on Platform A, in the Middle Ground Shoal Field' of Cook Inlet. XTO notified the AOGCC bye-mail on September 6, 2005 after discovering the pressure communication on the tubing annulus. The AOGCC agreed to allow XTO to continue injection since the rate was not accelerating indicating inj ection was taking place below the packer while we arranged to perform a temperature survey. The injection history for the past 4 months is attached that illustrates the average rate was ±500 BWIPD @ 3,550 psi prior to the backside leak. The pressure on the tubing annulus (TCA) is normally 100 psi but as seen in mid June, this pressure slowly increased to 2,600 psi while the WH injection pressure remained steady @ 3,550 psi. Keeping in mind that diesel is the fluid on the backside being compressible & weighing less than the 8.5 ppg injected water, some phenomenon was occurring since the TCA pressure was not greater than the WH pressure. The TCA pressure was bled-off to 300 psi on June 22nd to see if it would rebound. The pressure was slow to build from 300 to 675 psi in 32 days, which did not duplicate the sharp pressure increase in the prior month. Reviewing the backside pressure during the summer of 2004, a similar response of the TCA pressure was seen slowly climbing from 100 to 700 psi. I would interpret this being caused from the warmth of the summer months making the equipment run hotter, transferring the heat to the injection water which in turn causes the diesel on the TCA to expand. On September 8, 2005, XTO ran a temperature survey on the well after a 7 hour shut-in period. The attached plots that were downloaded from Pollard Wireline illustrate that the temperature profile remained linear from 2000' to the packer @ 7,670' TVD, which would indicate the injection was staying below the packer. ./ ) 2 Based upon the data provided, XTO is requesting the approval from the AOGCC to continue injection operations on the A41A-IILN by way of the Administrative Relief by Rule 9 of Area Injection Order for a variance to Rule 6. This injector provides necessary pressure support to 6 offset producers in the northwest section in the West Flank. XTO will be conducting our yearly wellbore review the last week of September and this injector will be proposed for a workover'tO'pull the completion and retñëve the coÌI tubing fish in the top of the 3-112" slotted liner. It is anticipated that XTO will commence a drilling and workover program in the 1 st quarter of 2006. In the meantime, the injection pressure and rate will be monitored on a daily basis and will be shut-in immediately if the inj ection rate accelerates above the normal operating history. This data will be send via e-mail to the AOGCC on a monthly basis. Please notify me of approval or if any other action is required to continue injection operations. Please contact me with any questions @ 432-620-6743. S incerel y, 9cJß-f¡/ Paul L. Figel Engineering Manager Attachments: 1. Application for Sundry Approval Form 10-403 2. A41A-IILN Injection Tabular Data & Plot 3. Pollard Wireline Temperature Survey 4. Wellbore Diagram Cc: Scott Griffith Tim Smith 1000 900 800 700 c a.. 600 ~ m $' (II 500 D:: c 0 ;::¡ () 400 (þ :5 300 200 100 0 5/1/05 XTO Energy Inc. MGS A41A-11LN Injection Data Permit #95-119 5000 Note the 350 psi difference is due to hydrostatic of diesel on the TCA & 8.5 ppg inj water 4000 3000 ïñ c. 2000 1000 6/1/05 o 10/1/05 711105 8/1/05 9/1/05 ) XTO Energy, Inc. ) A41A-11 LN Injection Data Permit: 95-119 Sundry: Date Inj Rate, BPD WHP, psi Tbg Ann Press, psi Surf Csg Press, psi Comments 5/1/05 488 3550 400 43 5/2/05 487 3550 400 43 5/3/05 477 3550 450 0 5/4/05 473 3550 400 0 5/5/05 503 3550 450 0 5/6/05 517 3550 200 3 5/7/05 545 3550 150 3 5/8/05 533 3550 150 5 5/9/05 553 3550 175 5 5/10/05 552 3550 175 5 5/11/05 553 3550 175 5 5/12/05 530 3550 150 5 5/13/05 499 3550 150 5 5/14/05 492 3550 150 5 5/15/05 487 3550 150 5 5/16/05 487 3550 150 5 5/17/05 495 3550 150 5 5/18/05 497 3550 100 4 5/19/05 499 3575 100 13 5/20/05 500 3575 100 13 5/21/05 376 3600 75 13 5/22/05 502 3550 100 12 5/23/05 505 3550 100 12 5/24/05 526 3550 100 15 5/25/05 526 3550 125 17 5/26/05 552 3600 100 17 5/27/05 552 3600 100 15 5/28/05 532 3600 175 15 5/29/05 511 3500 225 15 5/30/05 536 3500 300 15 5/31/05 536 3550 250 15 6/1/05 507 3550 250 15 6/2/05 528 3550 200 15 6/3/05 538 3550 225 15 6/4/05 510 3550 400 15 615/05 474 3550 250 15 6/6/05 517 3625 400 15 6/7/05 473 3550 900 15 6/8/05 507 3550 1150 18 6/9/05 516 3550 1250 18 6/10/05 514 3550 2000 18 6/11/05 551 3550 2200 18 6/12/05 557 3550 2450 18 6/13/05 563 3550 2600 18 6/14/05 566 3550 2600 18 6/15/05 561 3550 2600 18 6/16/05 563 3575 2650 15 6/17/05 563 3575 2650 15 6/18/05 563 3575 2675 15 6/19/05 548 3575 2675 5 ) XTO Energy, Inc. Date Inj Rate, BPD WHP, psi Tbg Ann Press, psi Surf Csg Press, psi Comments 6/20/05 537 3575 2650 5 6/21/05 524 3575 2675 5 6/22/05 531 3575 2725 6 Bleed-off Press 6/23/05 522 3550 300 7 6/24/05 513 3550 400 7 6/25/05 514 3550 400 6 6/26/05 512 3575 400 6 6/27/05 500 3550 400 6 6/28/05 496 3550 450 6 6/29/05 476 3550 450 6 6/30/05 488 3575 475 6 7/1/05 492 3575 475 6 7/2/05 484 3550 500 6 7/3/05 486 3575 500 6 7/4/05 487 3575 500 6 7/5/05 483 3575 500 8 7/6/05 478 3575 525 8 7/7/05 474 3575 550 10 7/8/05 477 3575 550 8 7/9/05 473 3600 550 8 7/10/05 471 3600 550 8 7/11/05 476 3600 550 8 7/12/05 469 3600 550 8 7/13/05 452 3550 600 8 7/14/05 465 3575 600 8 7/15/05 457 3575 600 8 7/16/05 463 3575 610 8 7/17/05 469 3575 610 9 7/18/05 461 3575 610 9 7/19/05 454 3575 610 9 7/20/05 474 3575 650 8 7/21/05 452 3600 650 8 7/22/05 460 3600 650 8 7/23/05 459 3575 675 8 7/24/05 453 3600 50 8 Bleed-off Press 7/25/05 442 3550 50 8 7/26/05 446 3550 75 8 7/27/05 443 3550 75 8 7/28/05 444 3550 90 8 7/29/05 444 3550 90 8 7/30/05 445 3550 200 8 7/31/05 439 3550 300 8 8/1/05 451 3550 350 8 8/2/05 452 3550 225 8 8/3/05 461 3550 350 10 8/4/05 428 3550 400 8 8/5/05 458 3550 400 9 8/6/05 456 3550 400 10 8/7/05 449 3550 400 9 8/8/05 450 3550 400 10 8/9/05 452 3550 425 10 8/10/05 446 3550 400 10 8/11/05 449 3525 425 10 8/12/05 452 3525 400 10 8/13/05 452 3525 425 10 8/14/05 458 3525 400 10 8/15/05 458 3525 400 10 2 ) XTO Energy, Inc. Date Inj Rate, BPD WHP, psi Tbg Ann Press, psi Surf Csg Press, psi Comments 8/16/05 462 3525 400 10 8/17/05 460 3525 400 10 8/18/05 473 3550 350 10 8/19/05 476 3550 375 10 8/20/05 480 3525 310 10 8/21/05 478 3550 325 10 8/22/05 466 3550 340 10 8/23/05 468 3550 345 10 8/24/05 475 3550 345 10 8/25/05 533 3600 325 10 8/26/05 536 3600 275 10 8/27/05 526 3600 275 10 8/28/05 515 3600 300 10 8/29/05 512 3600 300 10 8/30/05 515 3600 325 10 8/31/05 499 3610 350 10 9/1/05 519 3600 350 10 9/2/05 520 3600 325 10 9/3/05 368 3600 600 12 SO INJ for 10 hrs to repair Header 9/4/05 144 2300 100 12 Repair Header. Omni pure inj 9/5/05 156 2250 75 10 Repair Header. Omni pure inj 9/6/05 627 3550 3975 10 RWTI. 9/7/05 615 3600 4000 12 9/8/05 280 3600 4000 15 SO 13 hr. Run Temp Survey. 9/9/05 382 3600 3175 15 Own 3 hrs. Fin WL Survey. RWTI. 9/10/05 422 3625 3975 15 9/11/05 411 3625 4000 0 9/12/05 412 3625 4000 0 9/13/05 408 3625 4000 0 9/14/05 411 3625 4000 0 9/15/05 414 3625 4000 0 9/16/05 423 3650 4000 0 9/17/05 428 3650 4000 0 9/18/05 411 3650 4000 0 9/19/05 418 3650 4000 0 9/20/05 414 3650 4000 0 9/21/05 416 3650 4000 0 9/22/05 421 3650 4000 0 9/23/05 422 3650 4000 0 9/24/05 424 3650 4000 0 9/25/05 438 3650 4000 0 3 ;[19 MGS A41A-11LN WIW Cook Inlet, Alaska Leg 2, Conductor 12 API No.: 50-733-20179-03 Sidetracked: 8-6-95 A22-01 was P&A'd for the A41A-11 that was Spud in 3-7-86. 20" Conductor Csg @ 330' Surf Csg: 133/8",61#, K55. Set@ 1,990'. Cmt'd wI 810 sk. Top Job wI 170 sk. Intermediate Csg: 7", 26-29#, N80. Set @ 7,765'. Cmt'd wI 824 sk. 26# : Surf - 1,659' 29# : 1,659 - 7,765' Liner: 5", 18#, P11 0 STL. Set @ 10,743'. TOL @ 5,654'. TOL has isolation packer. Cmt'd wI 560 sk. Liner: 3-1/2" 9.3# J55 BTC slotted. Set @ 12,045'. TOL @ 10,680'. TD:12,047' MD (10,046' TVD) ) Present Completion , ~ c!~ x::J l I I I I I ,. . J J J J J J J '~ PLF 9-26-05 KB: 35' Water Depth: 73' MSL Tbg: 2-7/8" 6.5# L80 8rd EUE (used) & 2-3/8" 4.7# L80 8rd EUE (new) X-over 2-7/8" x 2-3/8" @ 5,520' Pkr & Tbg Set on 10-21-95. "x" Nipple (2.313" ID) @ 340' GLM MD TVD GLV 1 1947' 1895' Dummy 2 3726' 3519' Dummy 3 5096' 4724' Dummy 4 6208' 5709' Dummy 5 7094' 6521' Dummy 6 7734' 7122' Dummy 7 8346' 7612' Dummy (3ea 2-7/8" D-SO & 4ea 2-3/8" U-SO GLM's) 1 Jt 2-3/8" 4.7# L80 8rd EUE X Nipple (1.875" ID) @ 8,391' 1 Jt 2-3/8" 4.7# L80 8rd EUE 5" Baker DB Permanent Packer @ 8,430' 15' Sealbore Extension wI 15' seals inside 1 Jt 2-3/8" 4.7# L80 8rd EUE 2-3/8" XN Nipple (1.791" ID) @ 8,482' 1 Jt 2-3/8" 4.7# L80 8rd EUE WLREG @ 8,515' Isolated Perfs in 7" behind 5" liner: AS 6084'-6136' FL(1): 6574'-6638' FL(2): 6659'-6677' FP: 6746'-6772' FS(1): 6845'-6857' FS(2): 6870'-6881 ' GB(1): 7157'-7230' GB(2) 7251 '-7289' HZ-HR: 10,530'-10,666' @ 6 spf Fish @ 10,935' Consists of GS Fishing neck, Baker Mach 1 mtr, X-over & Baker junk mill. Length = 10.5' wI 1.78" max 00. Lost in hole 4-27-01 Slotted Liner: HR-HN, HN-HK, HK-HI, HI-HE & HE-HC Re: A41A-l1LN (PTD 195-119) ) ') Subject: Re: A41 A~ 11 LN (PCrD 195~ 119) . FnHn: :;TI10in~'$ Maul1der<tom-,-maunder@~dJ11in:state.ak.ü9. Dafe:··fri, 28 Oct 200510:57:37-0800 '. . . . .' '. ........... . .' ". '. '. ~3jt~::Ji~@=¡~~~¡~J~;~:¡~~~:~f£~~~~Kfi~o'iZtl'D¡)Lili&j$;i:~:k;;i'5J;}~~~~'1~1!0~)~iKri'1¿~i¡r~~1&~ - . '. , Paul, By copy of this email, you have approval to continue injection into the subject well. You should implement the additional monitoring and reporting as related in the document accompanying the sundry you submitted. It has been determined that approving a sundry to continue injection is not appropriate at this time. It is acknowledged that you are planning to workover this well to repair the integrity problem within the next 3 - 4 months. When you plans are determined, please submit a sundry for that work. If XTO determines not to per~orm the workover, at that time an application for administrative approval would be in order. Sorry for any confusion this process may have caused. Please call or message with any questions. We look forward to receiving the work application. Tom Maunder, PE AOGCC Paul Figel@xtc)energy.comwrote, On 10/17/2005 5:40 AM: Yes, We are going to pull the A41A-l1LN & the A11-l3RD2 WIW's & repair the press communication. I need to order new packers, tubing hangers & tubing. I'm aiming for Dec/Jan based upon the timing of the equipment. Paul Maunder <tom. maunder@admin.state.ak.us> T'õ..··pãüI·...·F·fger.......··................·......·..··.........·..·...···..·...··...... ::P.!!!-.~~).-~.ªc9s:..~..if!!~:~.Q.~.!}.~.!:.9Y...:.!:.9_~.> PM A41A-llLN Thomas 10/14/2005 05:32 cc Subject Paul, I think you had indicated that you all had just had a "well review". Was there any consideration to working over this well in the new campaign?? Tom Maunder, PE AOGCC t ":--~ -~'-~_. '. ,-. .\~S~(è. 'i~q \té~C')~"_ ~?~.~.... le -Ð, -..--. -~ .<k ;:- ~>.ì~~\-\'~~= .. ~ q'-Q: \.X\:r .kc:d.Q. ~~..~~·C~...._ ._~~-~~. ~\)\Ô \)~\~~r . ___ w-:-~ ~~ '109~~~~, ~ s.{.~-WeQ "... of 1 -roM. - . PmboJt,ltt· Ol . Ql;UL.(er" ~ ./.0 ~; ;J: tel fes,ø-\ft ~ ~~ pllXf-SS ¥ vJåt ~ ( rU.:Y~ ~)j ~.. couM ~ ~Je W'. n~ ~vzJ... , &v~o'r ~~ 1&) \ç: rws~ . AtJrQ~AA wo~k - . ~. "If"} "ç f\e&;W ctRer C\pp(DP(~ ~ _ (.A.;br~, J( tv\¡ --.--.------.-.-" ..... 10/28/2005 10:59 AM 9/14/2005 10:40 AM 10f2 Paul, et al: Was there any change in the next annulus out?? Tom Reese@xtoenergy.com, ª.S:~t t G r iff i t}:!~0.:.!::.S?.~_~~.E9Z.~S:~.~ Subject Re: Press Communication on MGS A41A-11LN WIW 09/06/2005 05:50 PM cc Paul Figel@xtoenergy.com To Thomas Maunder <tom maunder@admi n.state.ak.us> ,~);.r:,f;\:Î'~~~Ü¡(::~ 'I ~,~ ç i¡) I} ..-.;;; I~¥.!- .\ J ~,II,-' ""~"I 'I. ~I ,~....:) t" !i ( I Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432-620-6743 Mobil: 432-553-5217 Fax: 432-687-0862 Paul I will keep you informed. We are on the well today running the temp survey. Should have results back Friday or Saturday. Tom, Attached is the Injection - Press Plot with the Tabular data from May 1st to today's report. As you will see in the plot for mid June, the tbg annulus pressure slowly starting rising up to ±2600 psi. At the time, I was thinking a dummy valve in a gas lift mandrel was starting to leak. We manually bleed off the press & it stayed around 500 psi for the next 6 weeks. I was thinking or guessing that some of this press could be the fact that there is diesel on the backside & not regular treated pkr fluid water that was expanding as the water injection temp was rising during the summer months. But now it's obvious something failed as the tbg ann pressure is within 500 psi of the injection press. So if you were wondering as to why the WHP & TCA pressures are not equal, it's not a bad valve but the difference in hydrostatic pressure of 8.5 PPG FIW & 6.8 ppg diesel. (See attached file: A41A-11LN Inj Plot. xIs) Subject: Re: Press Con1munication on MGS A41A-IILN WIW .' \ c From: Paul_Figel@xtoenergy.com \115-' Date: Thu, 08 Sep 2005 16:08:54 -0500 .""\ TØ: Thomas Maunder <tom_maunder@admin.state.ak.us>, jim_regg@admin.state.ak.us. cc: Scott_ Griffith@xtoenergy.com, Tom_Reese@xtoenergy.com ) ) Re: Press Communication on MGS A41A-IILN WIW Re: Press Communication on MGS A41A-IILN WIW ) ) Do you all have any electronic data that could present the pressure data for this well for the last 90 days?? Paul, this would be similar to the electronic plot you send in on that other well. Tom Maunder, PE AOGCC Paul Figel@xtoenergy.com wrote, On 9/6/2005 10:30 AM: Tom, I got a phone call from Tom Reese this morning that an injector on Platform A, A41A-11LN, has press on the tbg annulus. On Sat, Sept 3rd, all the water injectors were SI to fix the header system. When they were brought on line this morning, the A41A-11LN had equal pressure on the tbg annulus as the WHP @ 4,000 psi. Our slickline operator is coming back on days on Wed. We will have a quick temp survey run on the well to see if the injection is taking place below the pkr. Attached is the wellbore diagram. Paul (See attached file: A41A-11LN Current WBD 3-30-04.doc) Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432-620-6743 Mobil: 432-553-5217 Fax: 432-687-0862 > Inj Content-Type: applicationlmsexcel Content-Encoding: base64 20f2 9/14/2005 10:40 AM XTO Energy Inc. MGS A41A-11LN Injection Data Permit #95-119 1000 5000 900 800 700 -~ - - -. --- I{Þ - --., ~ 4000 C Q. ~ m a) ... ns a::: c: o :¡:; CJ CÞ :s 600 3000 '0 a. ... 400 " j þ SWI to Repair Header - Bleed-off Sept 3rd - 5th ~ 300 Press . ~ t 200 . ~þ ~........... - 100 ....... ....... .. 2000 1000 I 0 5/1/2005 10/1/2005 -+-Inj Rate, BPD ~ WHP, psi ---.- Tbg Ann Press, psi ---*- Suñ Csg Press, psi ------ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission FROM: Jeff Jones Petroleum Inspector DATE: Wednesday, June 02, 2004 SUBJECT: Mechanical Integrity Tests XTO ENERGY TNC A4IAIILN MGSA41AIILN I q~ / I J 1 TO: Jim Regg ';~;<'" L:! "'Ii CYi P.I. Supervisor " t¡'! Src: Inspector Reviewed By: P.I. Suprv :y;:::..-, Comm NON-CONFIDENTIAL Well Name: MGS A41A11LN API Well Numbe 50-733-20179-03-00 Inspector Name: Permit Number 1951190 Inspection Date: Jeff Jones 5/1 0/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: A41AIIL Type Inj. S TVD 10045 IA 40 2125 2025 2000 N P.T. 1951190 TypeTest SPT Test psi 1920.75 OA 78 78 78 78 Interval 4YRTST PIF P Tubing 3640 3640 3640 3650 -- Notes: Pre-test pressures monitored & stable. Standard annulus pressure test performed, well passed MIT & is suitable for continued injection. Wednesday, June 02, 2004 Page I of I !. ~ "'""" ~TO ~~RGY 3000 North Garfield Suite 175 Midland, Texas 79705 432-682-8873 432-687-0862 (Fax) May 8, 2004 Alaska Oil and Gas Conservation Commission Attn: Mr. John Nonnan 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Submission of Report 10-404 for Well Operations for MGS A41A-11LN. Dear Mr. Nonnan: XTO Energy, Inc. hereby submits the Report of Sundry Well Operations Fonn 10-404 for the MGS A41A-11LN injector well, on Platfonn A, in Cook Inlet, AK. Please find attached the following infonnation for your files: 1. Fonn 10-404 Report of Sundry Well Operations 2. Daily Operations Report 3. Current Well bore Schematic Please contact me with any questions @ 432-620-6743. Sincerely, 9aJ tI. ¥ Paul L. Figel Sr. Production Engineer Cc: Doug Marshall Tim Smith RECEIVED MAY 1 2 2004 Alaska Oil & Gas Cons. Commission Anchorage no! C,1f\I ,f\' /"'"'\ STATE OF ALASKA ~ ALA&. ., \ OIL AND GAS CONSERVATION COMrvl....dION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Performed: Alter Casing 0 Change Approved Program 0 2. Operator Name: Suspend U Repair Well 0 Pull TubingD Operation Shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic 0 PerforateU WaiverU Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 95-119 6. API Number: 50-733-20179-03 9. Well Name and Number: A41A-11 LN 10. Field/Pool(s): Middle Ground Shoal Other U 3000 N. Garfield, Suite 175, Midland, TX 79705 7. KB Elevation (ft): 116'KB 8. Property Designation: Platform A,Leg 2,Cond 12@ 1677' FSL & 367' FEL, Sec.11, T8N, R13W SM 11. Present Well Condition Summary: Exploratory 0 Service 0 3. Address: Total Depth measured 12,047' feet true vertical 10,045 feet Effective Depth measured 11,950' feet true vertical 9,983' feet Casing Length Size MD Structural Conductor Surface 1,990' 13-3/8" 1,990' Intermediate 7,765 7" 7,765' Liner 1 5,089' 5" 10,743' Liner 2 1,365' 3-1/2" 12,045' Plugs (measured) Junk (measured) TVD Burst Collapse 1,934' 3090 psig 1540 psig 7,151 7240 psig 5410 psig 9,196' 13940 psig 13450 psig 10,045' Slotted Slotted Perforation depth: Measured depth: 12,045' True Vertical depth: 9,930' Tubing: (size, grade, and measured depth) 2-7/8" & 2-3/8" L80 RECEIVED MAY 1 2 2004 Alaska 011 & Gas CuOi. Commission Anchorage Packers and SSSV (type and measured depth) Baker DB 8,430' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10,530-10,666' and 10,743-12,045' Treatment descriptions including volumes used and final pressure: 10,000 gal 10% HC!. Inj @ 1 BPM @ 3201 psi WHP. 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 399 137 1002 0 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well St~~fter proposed work: Oil r J 0' -Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 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: 304-104 Oil-Bbl Tubing Pressure 3626 3650 Service 0 x Contact Paul Figel Printed Name Paul Figel Signature 7J 4J. pi - f1¡I Form 10-404 Revised 12/2003 Title Sr. Production Engineer Phone 432-682-8873 ORIGINAL Date 5/11/04 RBDMS BFL MAY ,¡ 3 200\ ~ /"'"'\ ~ 1 Workover Report for A41A-IILN -'" .__I:h Objective: Coil Tbg Acid Stimulation First 04/27/2004 Report: AFE: 4/27/04 Unloaded boat w/coil tbg equipment. 400598 4/28/04 MIRU Coil Tubing Unit. Press tstd all lines to 4,000 psi. Function & tstd BOP's to 500 & 4,000 psi. 4/29/04 MU Baker Vortex wash tool & press tstd to 4,000 psi. Held pre-job safety mtg. RIH w/coil tbg @ 60 fpm while pmpg @ 1 BPM slick FIW. Stopped @ 10,800' in the 3-112" slotted liner. (Fish in liner @ 10,935'). Circ 15 bbls Flo-Vis sweep to surf. Pmpd a 48 bbl 70Q foam pill. SI the WH when the pill hit the end of coil tbg. Inj the foam pill @ 1 BPM (0.3 BPM liquid + 770 scf/m N2) foam rate into the 3-112" slotted liner. WHP 2,997 psi & CTP 4,937 psi. Pmpd 31 bbls 10% HCI @ 1 BPM w/WHP fr 2,997 to 3,502 psi. Pmpd 48 bbls foam pill w/WHP fr 2,094 to 3,399 psi. Pmpd 36 bbls of 10% HCI @ 1 BPM w/WHP fr 2,282 to 2,885 psi. Pmpd 48 bbls foam pill w/WHP fr 2,252 to 2,569 psi. Pmpd 36 bbls of 10% HCI @ 1 BPM w/WHP fr 2,529 to 3,122 psi. Pmpd 48 bbls foam pill w/WHP fr 2,371 to 2,845 psi. Pmpd 36 bbls of 10% HCl @ 1 BPM w/WHP fr 2,370 to 3,216 psi. Flushed acid w175 bbls of slick FIW @ 1 BPM. POOH to 10,700'. Opened WHo Std washing perfs in the 5" liner w120 bbls of 10% HCI fr 10,700'-10,500'. Made 2 passes @ 20 fpm. RIH to 10,700' & circ out acid w/lOO bbls of FIW to flowback tnk @ 2 BPM. SI WHo Inj 80 bbls of 10% HCI @ 1 BPM 5,338 psi CT press & 3,400 psi WHP. Made 2 passes fr 10,700'-10,500' @ 5 fpm. Flushed acid w/80 bbls of slick FIW @ 1 BPM, while making 2 passes fr 10,700'- 10,500' @ 5 fpm w/CT press @ 5,019 psi & WHP @ 3,201 psi. POOH w!coil tbg. SDFN. 4/30/04 RD coil tubing, prop & tnk equipment. Return well to injection. Loaded out boat. 5/1/04 5/2/04 5/3/04 5/4/04 5/5/04 5/6/04 5/8/04 Inj @ 984 BWIPD @ 2,900 psi WHP. Inj @ 1,248 BWIPD @ 3,500 psi WHP. Inj @ 1,310 BWIPD @ 3,650 psi WHP. Inj @ 1,217 BWIPD @ 3,600 psi WHP. Inj @ 1,096 BWIPD @ 3,600 psi WHP. Inj @ 1,079 BWIPD @ 3,600 psi WHP. Inj @ 1,093 BWIPD @ 3,600 psi WHP. 1"""\ ~ 2 5/9/04 Inj @ 1,083 BWIPD @ 3,600 psi WHP. 5/10/04 Inj @ 995 BWIPD @ 3,600 psi WHP. 5/11104 Inj @ 1,002 BWIPD @ 3,600 psi WHP. ;{tg MGS A41A-11LN WIW Cook Inlet, Alaska Leg 2, Conductor 12 API No.: 50-733-20179-03 Sidetracked: 8-6-95 A22-o1 was P&A'd for the A41A-11 that was Spud in 3-7-86. 20" Conductor Csg @ 330' Surf Csg: 133/8",61#, K55. Set @ 1,990'. Cmt'd wI 810 sk. Top Job wI 170 sk. Intermediate Csg: 7", 26-29#, N80. Set @ 7,765'. Cmt'd wI 824 sk. 26# : Surf - 1,659' 29#: 1,659 - 7,765' Liner: 5",18#, P110 STL. Set @ 10,743'. TaL @ 5,654'. TaL has isolation packer. Cmt'd wI 560 sk. Liner: 3-1/2" 9.3# J55 BTC slotted. Set @ 12,045'. TaL @ 10,680'. TD:12,047' MD (9,930' TV D) r--.. Present Completion ~ . . J J J J J J J ~f I I I I I I I ~ ~, PLF 3-30-04 KB: 35' Water Depth: 73' MSL Tbg: 2-7/8" 6.5# L80 8rd EUE (used) & 2-3/8" 4.7# L80 8rd EUE (new) X-over 2-7/8" x 2-3/8" @ 5,520' Pkr & Tbg Set on 10-21-95. "X" Nipple (2.313" ID) @ 340' GLM MD TVD GLV 1 1947' 1895' Dummy 2 3726' 3519' Dummy 3 5096' 4724' Dummy 4 6208' 5709' Dummy 5 7094' 6521' Dummy 6 7734' 7122' Dummy 7 8346' 7612' Dummy (3ea 2-7/8" O-SO & 4ea 2-3/8" U-SO GLM's) 1 Jt 2-3/8" 4.7# L80 8rd EUE X Nipple (1.875" ID) @ 8,391' 1 Jt 2-3/8" 4.7# L80 8rd EUE 5" Baker DB Permanent Packer @ 8,430' 15' Sealbore Extension wi 15' seals inside 1 Jt 2-3/8" 4.7# L80 8rd EUE 2-3/8" XN Nipple (1.791" ID) @ 8,482' 1 Jt 2-3/8" 4.7# L80 8rd EUE WLREG @ 8,515' Isolated Perfs in 711 behind 511 liner: AS 6084'-6136' FL(1): 6574'-6638' FL(2): 6659'-6677' FP: 6746'-6772' FS(1): 6845'-6857' FS(2): 6870'-6881' GB(1): 7157'-7230' GB(2) 7251'-7289' HZ-HR: 10,530'-10,666' @ 6 spf Fish @ 10,935' Consists of GS Fishing neck, Baker Mach 1 mtr, X-over & Baker junk mill. Length = 10.5' wi 1.78" max OD. Lost in hole 4-27-01 Slotted Liner: HR-HN, HN-HK, HK-HI, HI-HE & HE-HC. Lrwu; IVlll "lr\.-l1Ll'llVlU~J FYI. I recently got a 403 request for this well. I checked Bob's records and it appears that this MIT is late. According to the monthly information XTO submits, the well has integrity, however the "formal" every 4-year test appears to have been missed. Tom -------- Original Message -------- Subject: MIT 41A-11LN MGS Date: Thu, 15 Apr 2004 09:15:39 -0800 From: Tom Reese <Tom Reese@xtoalaska.com> ------ -- - --- Organization: XTO Energy, Inc. To: Tom Maunder <tom maunder@admin.state.ak.us> CC: Bob Fleckenstein <bob fleckenstein@admin.state.ak.us> Prb <tt-- ~q5"" -Htt- Tom, Here is the MIT form for A41A-11LN MGS with the correct casing information that you requested. I am e-mailing this from our onshore facility on Tom Reese's computer. You can e-mail back to this address if you like or I will be on my cell phone today 394-2454. I copied Bob on this but did not have Jim Regg (sp?) address. Would very much appreciate it if you could forward this along to him. Many thanks, Barney Phillips , , i Content-Type: application/vnd.ms-excel ,MIT MGS A41A-llLN.xls I C . b 64 I ontent-Encodmg: age I 10f! 4/21/20048:21 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test E-Mail to; Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: XTO ENERGY (Barney Phillips) FIELD I UNIT I PAD: MIDDLE GROUND SHOAL PLA TFORM A DATE: Apri/9, 2004 PTD: 95.119 S P SALT 7,683 7" 26 - 29# 6.5# 3,625 3,625 3,625 3,625 19:55 Well #: A41A-11 WATER 8,430 N-80 2-7/8 1921 51 2,100 2,100 2,100 COMMENTS: PTD: I Well #: COMMENTS: P I I PTD: I Well #: COMMENTS: I I PTD: I Well #: COMMENTS: PTD: I Well #: COMMENTS: I I I I TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: P.P.G. DIESEL GLYCOL SALTWATER 8.5 DRILLING MUD OTHER Grad. 0.44 WELL TEST: Initial 4 - Year Workover X Other Distribution: orig - Well File c - Operator c - DaUSMfet revised by loG. 8/6/00 c. Trip Rpt File c - Inspector OPERATOR REP SIGNATURE: T. Reese I AOGCC REP SIGNATURE: 2004-0409_MIT_MGS_A41A-11 LN.xls 4/21/2004 1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: þ)~ k sz'/' '-\/ 7~ xf:Ct; Abandon U Alter casing 0 Change approved program 0 2. Operator Name: XTO Energy Inc. 3. Address: Perforate U Waiver U Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. ~it to Drill Number: 95-119~<?)v¡1-{( \0 6. API Number: / 50-733-20179-03 Suspend U Repair well 0 Pull Tubing 0 Development Stratigraphic 0 0 Exploratory 0 Service 0 Annular Dispos. U Other 0 3000 N. Garfield, Ste 175, Midland, TX 79705 7. KB Elevation (ft): 9. Well Name and Number: 116' A41A-11LN 8. Property Designation: ../ .,¡ / 10. Field/Pools(s}: "A", Leg 2, Cond 12,1677' FSL & 367' FEL, S11.T8N,R13W,S.M. Middle Ground Shoal 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): PIU9S (measured) 12,047' ./ 10,045' .../ 11,950' 9,983' : Casing Length Size MD TVD Burst Structural Conductor Surface 1,990' 13-3/8" 1,934' 1,990' 7,765' 10,743' 12,045' Tubing Size: 7,151' 9,196' 10,045' Tubing Grade: L80 Intermediate 7,765' Liner 1 5,089' Liner 2 1,365' Perforation Depth MD (ft): 12,045' Packers and SSSV Type: 7" 5" 3-1/2" Perforation Depth TVD (ft): 9,930' Baker DB pkr 2-7/8" & 2-3/8" Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal l:d Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Junk (measured): 10,935' Collapse 3,090' 7,240' 13,940' Slotted 1,540' 5,410' 13,450' Slotted Tubing M[) (ft): 8,515' 8,430' 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: 4/19/04 Oil 0 Gas 0 WAG 0 GINJ 0 0 Service 0 0 Abandoned 0 0 WDSPL 0 Date: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact :~~::~:ame ?~ of. ~;I Phone 432/:::8873 Sr. Production E~~~:er r COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test .ø Mechanical Integrity Test 0 Location Clearance Plugged WINJ Paul Figel 4/2/04 Sundry Number: Î¡Ó 4 . /0 4 0 Other: '-\OC)Ù~S\ ßUÇ' ~~ \- ~"-:::. \>\~,,\",Ç) . - /. .., 1alJll SubsequentF ReqUIred! ~ ~ -nnûS~f\.. þPR AlaskaOita68sCOn.,. --.........~....I\ Ill., I'Q:RoIP'- Anchorage ~~ :/ BY ORDER OF Approvud b .""" ~ ~ , COMMISSIONER THE COMMISSJON Dat., ~ '6 " I t) t~: ! ~F~~crs ON REVERSE Su mit ¡Duplicate RECE IVI=""-- APR - 5 2004 ~TO ~~RGY 3000 North Garfield Suite 175 Midland, Texas 79705 432-682-8873 432-687-0862 (Fax) April 2, 2004 Alaska Oil and Gas Conservation Commission Attn: Mr. John Nonnan 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Request for Sundry Approval to acid stimulate injector well A41A-llLN. Dear Mr. Nonnan: XTO Energy, Inc. hereby submits its Application for Sundry Approval to acid stimulate well A41A- llLN on Platfonn A, in the Middle Ground Shoal Field of Cook Inlet. The injection rate on this well has dropped from 600 to 400 BWIPD over the last 12 months. This well provides pressure support to 5 wells in the West Flank Hemlock reservoir in Section 1. Four of these 5 wells have lost approximately 100 BOPD cumulative due to the drop in injection, most likely due to scale buildup. Therefore, the intent is to utilize coil tubing to acidize the 3-1/2" slotted liner (HR-HC) & the perforations in the 5" liner (HZ-HR). Please find attached the following infonnation for your files: 1. Fonn 10-403 Application for Sundry Approval 2. Job Procedure 3. Present Wellbore Schematic Please contact me with any questions @ 432-620-6743. Sincerely, 9aJcI.~ Paul L. Figel Sr. Production Engineer Cc: Doug Marshall Tim Smith RECEIVED APR - õ 2004 Alaska Oil & Gu ConI Comm;' . . SSlon Anchorage {)r-<',r"""11 I ¡ ~""" f, , Þ 11 I \j!\!~:/::_.'~\. ;[19 XTO ENERGY INC. MGS A41A-IILN COOK INLET, ALASKA COIL TBG ACID STIMULATION PROCEDURE WELL DATA: SURFACE CASING: 13-3/8" 61# K55. Set @ 1,990'. Cmt w/ 810 sx. Top Job w/ 170 sx. INTERMEDIATE CASING: 7" 26-29#, N80. Set @ 7,765'. Cmt w/ 824 sx. DRILLING LINER: 5" 18#, PlIO STL. Set @ 5,654 -10,743'. Cmt w/ 560 sx. PRODUCTION LINER: 3-1/2" 9.3# J55 BTC SLOTTED. Set @ 10,680 - 12,045'. TUBING: 2-7/8" 6.5# L80 8rd EUE from surface to 5,520'. 2-3/8" 4.7# L80 8rd EUE from 5,520 - 8,515'. PACKER: 5" Baker DB Perm Packer @ 8,430'. Set in Oct '95. PERFORA TIONS: HZ-HR: 10,530 - 10,666' @ 6 spf. SLOTTED SECTION: HR-HN, HN-HK, HK-HI, HI-HE & HE - HC @ 10,680 - 12,045'. BHST: 160 Deg F BHP: 3,500 psi SMALLEST ID: 2-3/8" XN Nipple 1.791" ID @ 8,482'. Inj @ 419 BWIPD @ 3,600 psi as of 3-29-04. PRESENT STATUS: OBJECTIVE: Recover the lost 200 BWIPD by acid stimulating the HZ-HR perfs & the HR-HC slotted csg using coil tbg. NOTES: . There is a fish in the top of the 3-1/2" Slotted Production Liner consisting of a Mud Motor & Mill @ 10,935' that was lost on the last coil tbgjob in April 2001. Do not attempt to run past 10,900' . . 1.70" gauge ring was run to 10,780' on 3-16-04. . NO KCL is required. Will use FIW as workover fluid. . NO ACID OR FILL IS TO BE PUMPED INTO THE PRODUCTION HEADER SYSTEM. A 250 BBL FLOWBACK TANK WILL BE USED TO HANDLE ALL ACID & FILL RETURNS. Procedure 3-30-04 XTO Energy Inc. MGS A41A-IILN Cook Inlet, Alaska 2 Materials Required: . 10,000 gal 10% HCL Acid ~ 6 gpt CI-27 Inhibitor ~ 5 ppt Ferrotrol-21O Iron Reducer ~ 2 gpt NE-118 Non-emulsifier Surfactant . 2,000 gal N2 (180,000 scf) ~ N2 Volume Factor @ 125 deg F @ 3500 psi BHP = 1100 scf/bbl Space . FR W -14 Friction Reducer for 500 bbl FIW Water . 1,000 lbs Soda Ash (Supplied by MI) . 20 bbl Flo- Visc Gel Pill (3#/bbl Flo- Visc) Equipment Required: . BJ 1.5" CTU . HP Triplex Pump . N2 Pump . Baker Oil Tool Vortex Tool . 250 bbl Flowback Tank ~ Mud Pump to be tied into tank to pump load to C44-14RD Disposal Well ~ Install 2" vent hose on top of tank to vent overboard ~ It is not necessary to add soda ash until Step #15 . Have a H2S monitor @ the Flowback Tank Procedure 3-30-04 XTO Energy Inc. MGS A41A-IILN Cook Inlet, Alaska 3 PROCEDURE: 1. MIRU BJ 1.5" Coil Tbg unit, triplex fluid pump, 10,000 gal 10% HCL & N2 Unit wI 2,000 gal N2. RU riser, BOP's & lubricator. Notify the AOGCC 24 hrs prior to the BOP Test. Press test lines to 4,000 psi with FIW. Function & press test Coil tbg BOP's to 500 & 4,000 psi. Bleed-off press through the XTO flowback ironIHP hose tied into the production header system. Max press is 4,000 psi. MU the Baker Vortex 1-11/16" wash tool. CTU operator to ensure all tools to be calipered before RIH. Smallest ID = 1.791" @ 2-3/8" XN Nipple @ 8,482'. 2. Hold safety meeting with all service & production personnel about the procedure, corrosive chemicals, and possible H2S exposure. 3. RIH wI Coil tbg @ 60 fpm while pumping @ 1 BPM slick FIW to 10,500'. Take returns to the 250 bbl Flowback tank. Slow rate to 10 fpm & cont to wash DH to 10,900' as max depth as to not hit the fish @ 10,935'. Stop short if necessary. 4. Stop wash tool @ 10,900' & circ a 20 bbl Flo- Visc sweep to surface. 5. Pump a 40 bbl 70Q foam pill (12 bbl FIW wlfoamer + 30,600 scf N2). SI the WH when the pill exits the coil tbg. SQZ the pill @ 1 BPM BH foam rate (0.3 BPM liquid + 770 scflm N2). 6. Pump 1,300 gal (31 bbl) 10% HCL @ 1 BPM. 7. Pump the 2nd 40 bbl70Q foam pill as in STEP #5. 8. Pump 1,500 gal (36 bbl) 10% HCL. 9. Pump the 3rd 40 bbl 70Q foam pill. 10. Pump 1,500 gal (36 bbl) 10% HCL. 11. Pump the 4th 40 bbl70Q foam pill. SD N2 unit. KEEP ENOUGH N2 TO BLOW CT DRY @ EOJ. 12. Pump 1,500 gal (36 bbl) 10% HCL. 13. Overflush acid wI 75 bbl slick FIW @ 1 BPM. 14. Pull wash tool up to 10,700'. Open the WHo Acid wash the perfs @ 1 BPM wI 840 gal acid from 10,700 -10,500' while making 2 passes @ 20 fpm. 15. RIH back to 10,700'. Circ out acid to flowback tank wI 100 bbl FIW. (Have 1,000 lbs soda ash in flowback tank). 16. SI the WHo Pump 3,360 gal (80 bbl) acid @ 1 BPM from 10,700 -10,500' while making 2 passes @ 5fpm. Procedure 3-30-04 . . XTO Energy Inc. MGS A41A.IILN Cook Inlet, Alaska 4 17. Overflush acid wI 80 bbl slick FIW @ 1 BPM from 10,700 -10,500' while making 2 passes @ 5 fpm. 18. POOH. Jet reel dry wI remaining N2. 19. RDMO BJ. Return well to injection. p?~ p( y Sr. Production Engineer '-{- z -o'f Kyle Hammond Vice President Operations Procedure 3.30.04 . ~ ;[tg MGS A41A-11LN WIW Cook Inlet, Alaska Leg 2, Conductor 12 API No.: 50-733-20179-03 Sidetracked: 8-6-95 A22-o1 was P&A'd for the A41A-11 that was Spud in 3-7-86. 20" Conductor Csg @ 330' Surf Csg: 133/8",61#, K55. Set @ 1,990'. Cmt'd wi 810 sk. Top Job wI 170 sk. Intermediate Csg: 7", 26-29#, N80. Set @ 7,765'. Cmt'd wi 824 sk. 26# : Surf - 1 ,659' 29# : 1,659 - 7,765' Liner: 5", 18#, P11 0 STL. Set @ 10,743'. TOL @ 5,654'. TaL has isolation packer. Cmt'd wI 560 sk. Liner: 3-1/2" 9.3# J55 BTC slotted. Set @ 12,045'. TOL @ 10,680'. TD:12,047' MD (9,930' TVD) 1% ~ ~ ~ Present Completion J ~ J~ ~j r % =><::% .~==-c. ~ ~ ~ % ~ ~ ~ % ~ -r ~ I I I I I I . . J J J PLF 3-30-04 KB:35' Water Depth: 73' MSL Tbg: 2-7/8" 6.5# L80 8rd EUE (used) & 2-3/8" 4.7# L80 8rd EUE (new) X-over 2-7/8" x 2-3/8" @ 5,520' Pkr & Tbg Set on 10-21-95. "X" Nipple (2.313" 10) @ 340' GLM MD TVD GL V 1 1947' 1895' Dummy 2 3726' 3519' Dummy 3 5096' 4724' Dummy 4 6208' 5709' Dummy 5 7094' 6521' Dummy 6 7734' 7122' Dummy 7 8346' 7612' Dummy (3ea 2-7/8" D-SO & 4ea 2-3/8" U-SO GLM's) 1 Jt 2-3/8" 4.7# L80 8rd EUE X Nipple (1.875" 10) @ 8,391' 1 Jt 2-3/8" 4.7# L80 8rd EUE 5" Baker DB Permanent Packer @ 8,430' 15' Sealbore Extension wi 15' seals inside 1 Jt 2-3/8" 4.7# L80 8rd EUE 2-3/8" XN Nipple (1.791" 10) @ 8,482' 1 Jt 2-3/8" 4.7# L80 8rd EUE WLREG @ 8,515' Isolated Peñs in 7" behind 5" liner: AS 6084'-6136' FL(1): 6574'-6638' FL(2): 6659'-6677' FP: 6746'-6772' FS(1): 6845'-6857' FS(2): 6870'-6881' GB(1): 7157'-7230' GB(2) 7251'-7289' HZ-HR: 10,530'-10,666' @ 6 spf Fish @ 10,935' Consists of GS Fishing neck, Baker Mach 1 mtr, X-over & Baker junk mill. Length = 10.5' wI 1.78" max 00. Lost in hole 4-27-01 Slotted Liner: HR-HN, HN-HK, HK-HI, HI-HE & HE-HC. WATER INJECTION REPORT PLATFORM A DISPOSAL WELL November-2002 A33-1 ILS A41A-I ILN A44-11 Al 1-13R2 Al 1-12 A33-14 A44-02 DATE & NOTES INJ 1NJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INI ANNU INJ INI ANNU INJ INJ ANNU INJ INJ ANNU 01-Nov-2002 1010 3600 51 597 3600 13 0 100 6( 288 3600 185 522 3600 250 508 3600 15~3 792 3600 02-Nov-2002 1000 3600 51612 3600 ~3 0 100 6( 297 3600 185527 3600 25(3 518 3600 10~ 776 3600 03-Nov-2002 976 3600 5( 606 3600 ~3 0 100 6( 316 3600 185546 3600 25~ 550 3600 10( 773 3600 04-Nov-2002 983 3700 50 603 3700 0 100 6( 344 3700 185240 3100 30~ 591 3700 75 784 3700 05-Nov-2002 975 3700 50 600 3700 0 100 60 179 3700 185609 3100 30~ 572 3700 75 773 3700 06-Nov-2002 968 3575 50 587 3650 0 100 60 246 3650 185592 3650 30( 606 3650 7.~773 3650 07-Nov-2002 970 3600 50 589 3650 0 90 60 242 3650 9(3 595 3650 22.s 609 3650 5: 769 3650 08-Nov-2002 965 3600 50 600 3650 0 100 60 255 3650 9~593 3650 22( 606 3650 5( 763 3650 09-Nov-2002 963 3600 50 592 3650 0 100 60 274 3650 9~589 3650 22.~ 601 3650 6( 764 3650 10-Nov-2002 957 3600 5~3604 3650 0 100 60 286 3650 9~590 3650 22.~ 608 3650 5( 759 3650 ! l-Nov-2002 832 3600 5(3550 3650 0 100 60 229 3650 9~504 3650 211 511 3650 5( 656 3650 12-Nov-2002 932 3600 45 605 3650 0 100 6~ 163 3650 9~594 3650 211 571 3650 50 748 3650 13-Nov-2002 926 3575 5~ 597 3650 0 100 6~ 182 3650 9~ 593 3650 22'. 561 3650 55 752 3650 14-Nov-2002 918 3550 5£ 594 3650 0 0 50 6~ 210 3650 171591 3625 22' 564 3650 55 743 3650 15-Nov-2002 920 2575 5£ 607 3650 0 0 50 6~3212 3650 151596 3650 20( 576 3650 50 741 3650 16-Nov-2002 914 3600 4.~610 3650 0 0 50 61 208 3650 151591 3650 22'. 571 3650 50 734 3650 17-Nov-2002 981 3650 41 648 3700 0 0 50 61 277 3650 151 705 3700 175] 762 3700 0 776 3700 18-Nov-2002 952 3650 4( 641 3700 0 0 50 6( 266 3700 151683 3700 150 709 3750 0 758 3700 19-Nov-2002 935 3650 4( 634 3700 0 0 50 6( 263 3700 151670 3700 150 689 3750 0 748 3700 20-Nov-2002 927 3650 4~ 618 3700 0 0 50 6( 273 3700 151 651 3700 150 655 3750 0 737 3700 2 l-Nov-2002 941 3625 4.~622 3700 0 0 100 5( 269 3700 14.~ 657 3700 175 668 3700 25 747 3700 22-Nov-2002 943 3625 8( 633 3700 (3 0 100 5( 283 3700 151 659 3700 t75 671 3700 (3 747 3700 23-Nov-2002 924 3625 45~617 3700 (3 0 100 5( 288 3700 150641 3700 175 648 3700 25 732 3700 24-Nov-2002 934 3625 45 613 3700 ~ 0 100 5( 284 3700 145 642 3700 175 651 3700 25 740 3700 25-Nov-2002 934 3625 45 631 3700 ~ 0 100 5( 296 3700 145647 3700 175 667 3700 25 732 3700 26-Nov-2002 942 3625 40 635 3700 0 100 5( 296 3700 145653 3700 175 673 3700 25 735 3700 27-Nov-2002 922 3625 45 609 3700 0 100 51 277 3700 145630 3700 175 638 3700 25 728 3700 28-Nov-2002 938 3625 85 630 3700 0 100 51 286 3700 145634 3700 175 640 3700 £ 735 3700 29-Nov-2002 907 3625 40 620 37~0 0 50 50 265 3700 140 605 3700 15~3 598 3700 2.~ 707 3700 30-Nov-2002 910 3625 40 602 3700 0 50 50 258 3700 140592 3700 15~ 582 3700 2-~709 3700 TOTAL 28,299 18,306 0 7,812 17,941 18,374 22,431 MAXIMUM 3,700 85 3,700 100 60 3,700 185 3,700 30~ 3,750 15£ 3,700 AVERAGE 943 3,584 49 610 3,672 0 85 57 260 3,670 142 598 3,631 206 612 3,677 42 748 3,672 # DAYS 30 30 0 30 30 30 30 12/12/2002 SCANNED I¥1AR I (~ 2003 WATER INJECTION REPORT PLATFORM A DISPOSAL WELL October-2002 A33-1 IL~ A41A-I ILN A44-11 Al 1-13R2 Al 1-12 A.33-14 A44-02 DATE & NOTF-~ INJ INJ ANNU INJ INI INJ INJ ANNU INJ INS ANNU INJ l~J INJINJ l~J INJ 0J-Oct-2002 961 3575 140 559 3625 (] 0 I00 75 380 3625 13G 550 3650 36( 557 3650 20( 709 3650 02-Oct-2002 965 3575 130 559 3625 (] 0 100 7£ 364 3625 13~ 550 3650 35( 554 3650 191 719 3650 03-Oct-2002 959 3575 130 552 3625 (] 0 100 7£ 375 3625 13~ 550 3650 35( 557 3650 191 707 3650 04-Oct-2002 963 3575 130 555 3625 (] 0 100 7£ 386 3625 13C 558 3650 35( 571 3650 191 716 3650 05-Oct-2002 1021 3575 100 598 3625 (] 0 100 7¢ 4~6 3625 IIC 650 3650 32( 741 3650 161 773 3650 06-Oct-2002 831 3575 80 516 3625 (] 0 100 7£ 367 3625 10C 537 3650 30( 589 3650 161 623 3650 07-Oct-2002 930 3575 50 537 3625 (] 0 100 7£ 265 3625 14C 561 3650 26( 655 3650 5( 703 3650 08-Oct-2002 959 3575 50 569 3625 C 0 100 7£ 272 3625 17£ 572 3650 27.~ 669 3650 6( 707 3650 09-Oct-2002 1014 3575 50 594 3625 ~ 0 100 7£ 345 3625 17C 652 3650 25( 710 3650 6( 774 3650 10-Oct-2002 979 3625 100 579 3650 C 0 100 65 342 3650 12'~ 607 3650 26( 612 3650 4( 745 3650 l 1-Oct-2002 971 3625 65 605 3650 ~ 0 I00 7£ 34l 3650 125 598 3650 26( 610 3650 4( 738 3650 12-Oct-2002 979 3625 65 610 3650 C 0 100 65349 3650 125604 3650 26( 618 3650 101 739 3650 13-Oct-2002 955 3625 65 570 3650 £ 0 I00 6( 332 3650 13C 586 3650 27( 589 3650 101 722 3650 14-Oct-2002 958 3625 65 562 3650 £ 0 100 6( 313 3650 135 586 3650 27/ 591 3650 Il( 718 3650 15-Oct-2002 952 3625 65 571 3650 £ 0 100 6( 320 3650 135 583 3650 27.~ 593 3650 111 705 3650 16-Oct-2002 974 3625 55 606 3650 £ 0 100 6( 343 3650 125 601 3650 25( 615 3650 9( 734 3650 17-Oct-2002 960 3600 60 572 3650 £ 0 100 6(343 3650 125587 3650 25( 595 3700 9~ 723 3700 18-Oct-2002 958 3600 50 598 3650 £ 0 50 6( 355 3650 12£ 593 3675 25( 612 3700 9~ 716 3650 19-Oct-2002 956 3600 50 585 3650 ~ 0 50 6( 351 3600 115 585 3650 251 594 3700 9( 712 3650 20-Oct-2002 951 3600 55 564 3650 £ 0 50 6( 345 3600 121 581 3650 25( 587 3700 9( 706 3650 21-Oct-2002 598 3600 60 350 3650 £ 0 50 6( 213 3650 121 369 3650 25( 373 3700 9t. 448 3700 22-Oct-2002 0 3600 60 0 3650 £ 0 50 6( 0 3650 12£ 0 3650 251 0 3700 ~ 0 3700 23-Oct-2002 0 2050 60 0 1000 £ 0 50 6( 0 950 12£ 0 2850 25( 0 3100 9.~ 0 2200 24-Oct-2002 29 1900 440 16 950 £ 0 100 6( 3 950 29( 7 2850 60( 8 3000 60( 11 2150 25-Oct-2002 326 1800 380 2~0 1950 f 0 100 6( 7 1850 30( 74 2850 55( 107 3025 52.' 119 2100 26-Oct-2002 700 1700 295 336 950 £ 0 100 6( 106 850 305 237 2800 60( 9 2950 60( 309 . ' 1950 27-Oct-2002 1430 3600 20 779 3650 £ 0 100 7( 227 3650 191 693 3650 17: 656 3650 1093 ~ 3650 28-Oct-2002 1225 3625 25 723 3700 £ 0 100 7I 270 3700 17£ 724 3700 151 793 3700 961 3700 29-Oct-2002 1046 3600 40 6~9 3650 £ 0 100 6( 267 3650 155 587 3650 17: 595 3650 824 3650 30-Oct-2002 1045 3475 50 614 3600 £ 0 100 6( 197 3600 185 501 3600 25( 463 3600 151 827 3600 31 -Oct-2002 1010 3600 50605 3600 C 0 100 6( 271 3600 185522 3600 25( 503 3600 151 808 3600 TOTAL 26.605 15,773 0 8,495 15,405 15,726 19,789 MAXIMUM 3,625 440 3,700 G 100 75 3,700 305 3,700 60( 3,700 60C 3,700 AVERAGE 858 3.371 98509 3,327 (] 0 90 65 274 3,315 153 497 3,544 29¢ 507 3,577 145638 3.453 # DAYS 29 29 0 29 29 29 29 11/12/2002 WATER INJECTION REPORT PLATFORM A DISPOSAL WELL September-2002 A33-11L~ A41A-I 1LN A44-11 Al 1-13R2 AIl-12 A33-14 A44-02 DATE & NOTES INI INJ INJ INJ IN/ INJ ANNU INJ II',lJ INJ l~J INJ I~l INJ I~J 01 -S¢p-2002 9gl 3625 265 610 3600 0 0 100 8C 429 3625 12.~607 3650 400 620 3650 200 722 3650 02-S¢p-2002 948 3625 285 605 3600 0 0 100 $£ 397 3625 13( 546 3650 400 523 3650 250 693 3650 03-Sep-2002 966 3625 275 608 3600 0 0 [00 8( 397 3625 13.'555 3650 400 543 3650 250 703 3650 14C 04-5ep-2002 952 3625 275 605 36~0 (3 0 100 8( 388 3625 14( 544 3650 400 532 3650 25(3 698 3650 13C 05-Sep-2002 870 3625 275 543 3600 (3 0 100 8( 308 3625 14( 446 3650 400 444 3650 25(3 585 3650 13£ 06-Sep-2002 1028 3625 275 596 3600 (3 0 100 8( 341 3625 14( 561 3650 4013 583 3650 25(3 755 3650 13C 07-$ep-2002 610 3625 25(3 608 3600 ~ 0 100 8( 343 3625 15( 539 3650 40~ 540 3650 22(~ 715 3650 12£ 08-8ep-2002 1116 3625 20C 583 3600 ( 0 100 8( 351 3625 150 540 3650 38(3 543 3650 22~ 719 3650 12C 09-S~p-2002 995 3625 215 594 3600 ¢ 0 100 8( 352 3625 150 540 3650 40(3 540 3650 22( 715 3650 14£ I 0-Sep-2002 983 3625 215 598 3600 ( 0 100 8( 357 3625 150 543 3650 40~ 544 3650 22£ 711 3650 14£ I 1 -$ep-2002 958 3625 215 586 3600 (~ 0 100 8( 354 3625 150 535 3650 40C 537 3650 22£ 705 3650 14( 12-Sep-2002 973 3600 21( 574 3650 ( 0 100 8( 349 3650 145 559 3650 39( 595 3650 225 715 3650 14( 13-$ep-2002 975 3600 21( 584 3650 0 I00 8( 338 3650 145 561 3650 375 565 3650 22( 717 3650 14-S¢I>-2002 957 3600 21( 573 3650 0 100 $( 334 3650 145 541 3625 375 541 3650 21£ 707 3650 9£ 15-Sep-2002 1015 3600 18£ 585 3650 0 100 8( 379 3650 130 627 3625 35£ 703 3650 15£ 746 3650 I0( 16-Sep-2002 958 3625 15£ 579 3650 0 100 8( 357 3625 125 560 3650 375 558 3650 17': 711 3650 9( 17-$ep-2002 955 3575 20( 566 3625 0 100 8ff 336 3650 135 548 3650 38£ 547 3650 225 699 3650 11£ I 8-$ep-2002 967 3575 19£ 573 3625 0 100 80 361 3625 135 554 3650 38( 556 3650 21£ 709 3650 11( t9-$ep-2002 953 3600 19( 561 3600 0 50 80 367 3600 140 543 3650 375 547 3650 20( 698 3650 105 20-$ep-2002 975 3550 18£ 574 3600 0 50 80 391 3600 130 561 3650 375 574 3650 20( 717 3650 1 I£ 2 I-$ep-2002 961 3550 17£ 568 3625 0 50 80 379 3600 13(3 546 3650 35£ 557 3675 20( 697 3650 10( 22-Sep-2002 966 3550 17.s 574 3600 0 50 80 382 3600 130 548 3650 35( 560 3650 20( 705 3650 10( 23-Sep-2002 941 3550 17( 567 3600 0 50 80 366 3600 13(] 543 3650 35( 545 3675 20( 691 3650 10( 24-$ep-2002 956 3550 17( 570 3600 0 50 80 367 3600 13(3 544 3650 35( 552 3675 20( 695 3650 10( 25-S¢p-2002 947 3550 16( 558 36~0 0 50 80 363 3600 13(3 541 3650 35( 556 3675 20( 691 3650 10( 26-Sep-2002 953 3550 16( 569 3600 0 100 70 363 3600 13(3 539 3650 37.' 545 3650 20( 691 3650 9.' 27-$¢p-2002 954 3550 15.' 566 3600 0 100 80 370 3600 13(3 540 3650 371 550 3650 20( 692 3650 95 28-Sep-2002 964 3550 14( 560 3600 0 100 80 370 3600 13(3 546 3650 37.' 558 3650 20( 701 3650 29-$ep-2002 947 3550 15( 566 3600 0 I00 80 359 3600 13(~ 532 3650 37.' 541 3650 20( 695 3650 IiX 30-Sep-2002 954 3550 14( 555 3625 0 100 70 364 3625 13(3 538 3650 35( 547 3650 19( 704 3650 9( TOTAL 2g,678 17,358 0 10,912 16,427 16,646 21,I02 MAXIMUM 3,625 285 3,650 100 80 3,650 150 3,650 40( 3,675 250 3,650 14( AVERAGE 956 3,590 20.~ 579 3,612 0! 0 88 79 364 3,620 136 548 3,648 37c, 555 3,653 212 703 3,650 Ill # DAYS 30 30 0 30 30 30 30 10/14/2002 WATER INJECTION REPORT PLATFORM A I DISPOSAL WELL June-2002 A33-1 I!L$ A41A-I ILN A44-11 Al 1-13R2 Al 1-12 A33-14 A44-02 DATE & NOTES INJ INJ~ INJ INJ INJ IHJ ANNU ][NJ INJ ANNU IHJ IiNJ ANNU [NJ LNJ ANNU INJ INJ ANNIJ 0 l-Jun-2002 1077 332 12C 628 3600 0 0 100 120 344 3600 1! 625 3650 150 636 3600 0 724 3650 02-Jun-2002 1089 12C 624 3600 0 0 100 120 349 3600 1.~621 3650 151~ 628 3600 0 717 3650 03-.1un-2002 1081 3625 13£ 612 3600 0 0 100 120 352 3600 l.' 617 3650 150 615 3600 0 718 3650 (N--Jun-2002 1105 3625 14( 613 3600 0 0 I00 120 352 3600 1.~ 609 3650 15~ 624 3600 0 710 3650 05Jun-2002 1033 3,6~0 14C 606 3600 0 0 100 120 352 3600 1' 600 3650 15C 584 3600 0 706 3650 06-Jun-2002 1070 33C~00 14C 621 3600 C 0 100 110 358 3600 1( 607 3650 16~ 609 3600 0 717 3650 07-Jun-2002 1072~55 15£ 623 3600 ~ 0 100 115 361 3650 1.' 606 3650 195 604 3650 0 724 3650 08-Jun-2002 1076 3 16C 610 3600 0 0 100 115 366 3600 l! 620 3650 20~ 614 3650 0 729 3650 09-Jun-2002 I064 3625 16C 591 3600 0 0 100 115 360 3625 I~ 603 3650 201] 604 3650 0 721 3650 10-$un-2002 1075 3625 16C619 3600 0 0 100 115 364 3625 1.'613 3650 20~ 619 3650 0 733 3650 11 -]un-2002 1056 36~25 165 606 3600 ~ 0 100 115 360 360 I.~ 600 3625 20~ 599 3650 0 721 3650 12-Jun-2002 1072 3525 17£ 609 3650 ~ 0 100 115 358 3625 l! 612 3650 200 614 3650 0 732 3650 13-Jun-2002 1052 3~25 17£ 590 3650 0 0 100 Il5 352 3625 1.~ 598 3650 201] 597 3650 0 715 3650 14-Iun-2002 1065 3,6?-5 17C 599 3650 0 0 100 I15 354 3625 1: 611 3650 200 607 3650 0 730 3650 15-1un-2002 1049 3625 17£ 557 3650 0 0 100 II5 350 3625 l.' 590 3650 20~ 582 3650 0 7131 3650 16-Jun-2002 1050 3~25 21C 552 3650 0 0 100 115 314 3625 11( 591 3650 20~ 587 3650 0 707 3650 17-Jun-2002 1057 3~25 21£ 597 3650 0 0 100 115 344 3625 11( 604 3650 20~ 613 3650 0 723 3650 18-Jun-2002 1056 3625 21£555 3650 0 0 100 115 342 3625 11{ 601 3650 20~ 602 3650 0 727] 3650 19-Iun-2002 1053 3625 21£ 569 3650 0 0 100 115 347 3625 11( 596 3650 200 596 3650 0 721] 3650 20-Jun~2002 I(N-9 3625 21£ 569 3650 0 0 100 40 344 3625 11( 596 3650 175 595 3650 0 723{ 3650 2 l-Jun-2002 1049 3625 21C 569 3650 0 0 100 40 345 3625 111 597 3650 175 598 3650 0 7281 3650 22-Jun-2002 1040 3625 225560 3625 0 0 {00 40 341 3625 Il( 590 3650 200 591 3650 0 71~ 3650 23-Jun-2002 [046 3625 225559 3625 0 0 100 40316 3625 11.~588 3650 20~ 588 3650 0 717 3650 24-Jun-2002 1043 36~5 225561 3625 0 0 100 40344 3625 11.~554 3650 200 579 3650 0 713 3650 25-Jun-2002 1044 3625 2413 560 3625 0 0 100 50 346 3625 Il.' 585 3650 200 584 3650 0 712 3650 26-Jun-2002 10¢6 3625 25C 563 3625 '0 0 100 50 359 3625 Il.~ 586 3650 200 587 3650 0 711 3650 27-Jun-2002 I0~ 3625 245 562 3625 0 0 100 50 365 3650 11( 587 3650 200 591 3650 0 717 3650 28-J'un-2002 1034 3625 26C 561 3600 0 0 100 50366 3650 11( 577 3650 225 573 3650 0 703 3650 29-Jun-2002 1044 3625 255 565 3600 0 0 100 50 385 3650 11( 586 3650 200 591 3650 0 712 3650 30-$un-2002 1037 3625 27G 561 3600 0 0 100 50 380 3650 10.~ 577 3650 225 572 3650 (~ 700 3650 TOTAL 31,728 I 17,601 0 10,570 17,977 17,983 21,543 MAXIMUM 3,625 270 3,650 0 100 120 3,650 115 3,650 225 3,650 3,650 AVER. AGE 1,058 3,621 191 587 3,622 0 0 100 90 352 3,515 62599 3,649 190 599 3,640 718 3,650 [ # DAYS 30 I 30 0 30 30 30 30 07/11/2002 WATER INSECT1ON REPORT PLATFORM A DISPOSAL WELL August-2002 A33-1 IL~ A41A-I lin A44-11 Al 1-13R2 Al 1-12 A33-14 A44-02 AC'TI ANNU ACT ] ANNU AC'I" ] I ACT ] ] ACT [ I } ACT[ ANNU ACT ANNU DATE & NOTES INJ [NJ [NJ [NJ LNJ [NJ ANNL/ [NJ INJ ANNU [NJ [NJ ANNU INJ INJ [NJ 0 l-Aug-2002 959 3625 41(] 599 3650 0 0 100 7C 382 3650 135 545 3650 35C 545 3650 225 683 3650 120 02-Aug-2002 995 3625 40C 607 3650 0 0 100 7C377 3650 135 554 3650 35C 559 3650 225 700 3650 120 03-Aug-2002 100! 3625 395 614 3650 0 0 70 75 377 3650 140 557 3650 35C 562 3650 225 709 3650 125 04. Aug-2002 993 3625 39C 603 3650 0 0 100 8£ 377 3650 140 554 3650 375 564 3650 225 702 3650 125 05-Aug-2002 993 3625 375 603 3650 0 0 70 8£ 382 3650 135 558 3650 35C 570 3650 225 703 3650 125 06-Aug-2002 993 3625 375 608 3650 0 0 75 8£ 384 3650 135 560 3650 35E 568 3650 225 708 3650 120 07-Aug-2002 1012 3625 355 608 3650 0 0 75 8¢ 334 3650 150 . 562 3650 35( 581 3650 200 706 3650 120 08-Aug-2002 1000 3625 355 602 3650 0 0 75 8( 321 3650 150 560 3650 35( 570 3650 200 699 3650 120 09-Aug-2002 987 3625 355 609 3650 0 0 75 8( 317 3650 150 555 3650 35C 569 3650 200 699 3650 120 10-Aug-2002 996 3625 34~ 606 3650 0 0 75 8C 277 3650 170 557 3650 32C 577 3650 200 698 3650 120 11-Aug-2002 992 3625 34( 598 3650 0 0 75 8C 266 3650 170 556 3650 32( 571 3650 200 694 3650 120 12-Aug-2002 930 3625 34( 560 3650 0 0 75 8( 254 3650 170 527 3650 32(] 565 3650 200 656 3650 120 13-Aug-2002 987 3625 34( 573 3650 0 0 75 8C 322 3650 170 561 3650 32~3 632 3650 200 691 3650 120 14-Aug-2002 1085 3625 34t 629 3650 0 0 75 8( 464 3650 170 727 3650 32C 798 3650 200 814 3650 120 15-Aug-2002 999 3650 29£ 626 3650 0 0 100 8C 406 3650 125 617 3650 35C 605 3650 200 749 3650 75 16-Aug-2002 992 3650 305 626 3650 0 0 100 8( 399 3650 130 603 3650 375 596 3650 200 740 3650 95 17-Aug-2002 984 3625 31£ 620 3650 0 0 I00 8( 398 3650 130 592 3650 375 580 3650 200 735 3650 I00 18.Aug~2002 973 3625 32( 620 3650 0 0 100 8( 388 3650 135 578 3650 40C 567 3650 210 721 3650 110 19-Aug-2002 978 3625 31( 617 3650 0 0 100 8( 388 3650 135 584 3650 40~ 580 3650 200 718 3650 120 20-Aug-2002 975 3625 31( 613 3650 0 0 100 8( 390 3650 135 581 3650 40~ 575 3650 200 718 3650 120 2 l-Aug-2002 994 3625 30~ 618 3650 0 0 lO0 8( 410 3650 135 594 3650 39C 593 3650 200 728 3650 115 22-Aug-2002 986 3650 29C 616 3600 0 0 lO0 8( 410 3625 125 590 3650 40C 586 3650 200 718 3650 110 23-Aag-2002 965 3625 295 613 3600 0 0 100 8C 398 3625 130 569 3650 40~ 561 3650 200 713 3650 120 24-Aug-2002 1028 3625 295 615 3600 0 0 100 8C 405 3650 130 578 3650 40~ 574 3650 200 715 3650 120 25-Aug.2002 919 3625 295 614 3600 0 0 I00 8C 4OI 3625 130 568 3650 40~ 559 3650 225 714 3650 120 26-Aug-2002 972 3625 295 615 3600 0 0 100 8( 404 3625 130 571 3650 40~ 566 3650 225 711 3650 120 27-Aug-2002 968 3625 29~ 617 3600 0 0 I00 8C 406 3625 130 568 3650 40~ 562 3650 225 723 3650 120 2S-Aug-2002 955 3625 295 602 3600 0 0 100 8C 396 3625 130 557 3650 40~ 549 3650 225 693 3650 120 29-Aug-2002 96[ 3625 295 611 3600 0 0 100 8C 397 3625 135 560 3650 40~ 551 3650 225 707 3650 30-Aug-2002 974 3625 285 604 3600 0 0 100 8( 401 3625 135 570 3650 40~ 565 3650 225 717 3650 14{ 3 t.Aug-2002 987 3625 25C 606 3600 0 0 100 8C 409 3625 135 579 3650 40~ 588 3650 225 717 3650 14{ TOTAL 30.533 18,872 O I 1,640 17,792 17,988 22,099 MAXIMUM 3.650 41(] 3,650 0 I00 80 3,650 170 3,650 400 3,650 225; 3.650 14( AVERAGE 985 3,627 328 609 3,634 0 0 91 79 375 3,643 140 574 3,650 370 580 3,650 211i 713 3.650 I1~. # DAYS 3l 31 0 31 31 31 31 09116/2002 8CANNED MAR 1 0 2003 February-99 01 -Feb-99 02-Feb-99 03-Feb-99 04-Feb-99 05-Feb-99 06-Feb-99 07-Feb-99 08-Feb-99 09-Feb-99 I O-Feb-99 I l-Feb-99 12-Feb-99 13-Feb-99 14-Feb-99 15-Feb-99 16-Feb-99 17-Feb-99 18-Feb-99 · ! 9-Feb-99 20-Feb-99 2 l-Feb-99 22-Feb-99 23-Feb-99 24-Feb-99 25-Feb-99 26-Feb-99 27-Feb-99 28-Feb-99 TOTAL MAXIMUM AVERAGE # DAYS 03/08/99 · ,., ^ ~ , DISPOSAL WELL .... A34-14 A4 IAol ILN A44-11 Al 1-13R2 Al 1-12 A23-0 IR A12-12 A33o14 INJ 1NJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ INJ INJ ANNU INJ 1NJ ANNU INJ INJ ANNU INJ INJ ANNU , 743 3600 50 1253 3500 0 0. 52 58 53 3600 60 421 3600 25 1135 3600 3450 0 0 0 528 3600 50 796 3600 50 1248 3500 0 0 52 58 52 3600 60 461 3600 25 llll 3600 3450 0 0 0 532 3600 779 3550 50 1223 3500 0 0 52 56! 53 3550 60 450 3550 25 1088 3600 3450 0 0 0 518 3550 791 3550 50 1243 3500 0 0 50 56 52 3550 60 458 3550 10 '1105 3550 3430 0 0 0 526 3550 50 781 3550 50 1231 3500 0 0 50 571 49 3550 65 452 3550 15 1094 3600 3440 0 0 0 520 3550 783 3575 50 1237 3500 0 0 50 58 46 3575 65 452 3575 25 1093 3600 3440 0 0 0 516 3575 55 781 3600 50 1228 3500 0 0 50 581 47 3600 65 450 3600 25 1090 3600 3440 0 0 0 515 3600 781 3575 50 1231 3500 0 0 50 58 40 3575 65 450 3575 25 1091 3575 3440 0 0 0 515 3600 780 3600 50 1221 3500 0 0 50 59 42 3600 65 450 3600 25 1088 3550 3440 0 0 0 516 3600 60 799 3600 50 1239 3525 0 0 50 55 44 3600 65 460 3600 25 1109 3550 3440 0 0 0 540 3600 55 802 3600 50 1236 3550 0 0 50 58 44 3600 65 463 3600 50 1110 3550 3450 0 0 0 545 3600 40 797 3600 50 1234 3550 0 0 50 60 44 3600 60 460 3600 50 1107 3550 3450 0 0 0 538 3600 50 811 3600 50 1248 3550 0 0 50 60 43 3600 65 468 3600 50 1123 3550 3450 0 0 0 563 3600' 50 821 3600 50 1251 3550 0 0 50 60 55 3600 65 478 3600 50 !130 3600 3500 0 0 0 578 3600 30 816 3600 50 1255 3550 0 0 50 60 67 3600 70 477 3600 50 1129 3600 3475 0 0 0 569 3600 35 810 3600 50 1244 3550 0 0 50 62 56 3600 70i 471 3600 50 !119 3600 3475 0 0 0 561 3600 50 811 3600 50 1242 3550 0 0 50 62 54 3600 701 470 3600 50 1119 3600 3500 0 0 0 563 3600 40 800 3600 50 1225 3550 0 0 50 62 43. 3600 70 462 3600 50 1102 3600 3500 0 0 0 550 3600 45 826 3600 55 1263 3550 0 0 50 62 40 3600 70 476 3600 50 1139 3600 3500 0 0 0 569 3600 45 812 3600 55 1237 3550 0 0 50 59 44 3600 65: 467 3600 50 1117 ' 3650 3500 0 0 0 560 3600 40 810 3600 55 1237 3550 0 0 50 61 55 3600 65 465 3600 50 11!5 3650 3500 0 0 0 555 3600 45 754 3600 55 1151 .3550 0 0 50 62 38 3600 65 431 3600 50 1037 ' 3650 3500 0 0 0 515 3600 45 876 3600 55 1335 3550 0 0 50 63 43 3600 70 501 3600 50 1205 3650 3500 0 0 01 600 3600 50 813 3600 55 1240 3550 0 0 50 63 38 3600 70 466 3600 50 1118 3650 3500 0 0 0 560 3600 '50 812 3600 50 1240 3550 0 0 50 63 42 3600 70 466 3600 50 1118 3650 3500 0 0 O! 558 3600 50 812 3600 50 1238 3550 0 0 50 63 47 3600 70 465 3600 50 1114 3650 3500 0 0 ~ 558 3600 50 809 3600 50 1236 3550 0 0 50 63 49 3600 70 465 3600 50 1113 3650 3500 0 0 553 3600 50 816 3600 50 1239 3550 0 0 50 63 58 3600 70 468 3600 50 1118 3650 3500 0 0 Oi 563 3600 50 22,422 34,705 0 1,338 12,923 31,137 0 15,284 3,600 55 3,550 0 52 63 3,600 70 3,600 50 . 3,650 3,500 0 0 3,600 60: 801 3,593 51 1,239 3,533 0 0 50 60 48 3,593 66 462 3,593 40 1,112 3,604 3,472 O- 0 0 546 '3,594 48 28 28 0 28 28 28 0 28 SCANNED DEC 9 200 ....... · DISPOSAL WELL January-99 A34-14 A41A-I ILN A44-11 Al 1-13R.2 Al 1-12 A23-01R A12-12 A33-14 ~ i~ ~ !i i !! i ii ii! !iii!!ii INJ INJ ANNU INJ INJ ANNUI INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU · 0 l-Jan-99 767 3600 50 1299 3550 0 0 50 59 45 3600 60 430 3600 25 1187 3600 3350 0 0 0 468 3600 80 02oJan-99 710 3600 50 1228 3550 0 0 50 59 45 3600 60' 411 3600 25 1065 3600 3350 0 0 0 432 3600 80 03-Jan-99 771 3600 50 1261 3600 0 0 50 59 44 3600 60: 449 3600 25 1 ! 11 3600 3350 0 0 0 500 3600 80 04oJan-99 779 3600 50 1273 3600 0 0 50 59 45 3600 60 459 3600 25 1116 3600 3350 0 0 0 504 3600 80 05-Jan-99 762 3600 50 1244 3600 0 0 50 59 38 3600 60 449 3600 25 1088 3600 3350 0 0 0 491 3600 80 06-Jan-99 764 3600 50 1245 3600 0 0 50 59 38 3600 60 449 3600 25 1089 3600 3350 0 0 0 490 3600 80 07-Jan-99 758 3600 45 1240 3500 0 0 50 59 33 3600 60 446 3600 25 1083 3600 3400 0 0 0 487 3600 40 08-Jan-99 768 3600 45, 1249 3500 0 0 50 55 38 3600 60 451 3600 25 1092 3600 3420 0 0 0 497 3600 40 09-Jan-99 761 3600 45 1239 3500 0 0 50 55 39 3600 55 446 3600 20 1084 3600 3425 0 0 0 489 3600 45 lO-Jan-99 758 3600 45 1237 3500 0 0 52 60 38 3600 60 443 3600 20 1079 3600 3425 0 0 0 485 3600 50 1 l-Jan-99 748 3600 45 1223 3500 0 0 52 60 34 3600 60 436 3600 25 1068 3600 3425 0 0 0 479 3600 50 12-Jan-99 754 3600 45 1236 3500 0 0 52 611 41 3600 60 439 3600 25 1078 3600 3450! 0 0 0 484 3600 55 13-Jan-99 770 3600 50 1255 3600 0 0 52 62: 49 3600 60 462 3600 25 1112 3600 345ff 0 0 0 529 3600 0 14-Jan-99 795 3600 50 1272 3500 0 0 52 62 53 3600 60 488 3600 50 1139 3600 3450 0 0 0 570 3600 15 15-Jan-99 792 3600 50 1268 3550 0 0 52 62 47 3600 60 487 3600 25 1134 3600 3450 0 0 0 562 3600 20 16-Jan-99 754 3600 50 1234 3500 0 0 52 62 38 3600 60 460 3600 50 I087 3600 3400 0 0 Ol 500 3600 80 17-Jan-99 830 3600 50 1281 3550 0 0 52 58 33 3600 60 501 3600 50 1156 3600 3450 0 0 O! 589 3600 20 18-Jan-99 804 3600 50 1262 3550 0 0 52 60 33 3600 60 487 3600 50 1125 3600 3450 0 0 0 541 3600 40 19-Jan-99 784 3600 50 1241 3500 0 0 52 60 27 3600 60 470 3600 50 1102 3600 3450 0 0 0 514 3600 45 20-Jan-99 792 3600 50 1250 3500 0 0 52 60 32 3600 60 472 3600 50 1109 3600 3450 0 0 0 523 3600 40 2 l-Jan-99 784 3600 55 1237 3500 0 0 52 59 34 3600 60 467 3600 25 1104 3600 3450 0 0 0 523 3600 40 22-Jan-99 804 3600 55 1266 3500 O 0 52 59 35 3600 60 477 3600 25, 1120 3600 3450 0 0 0 533 3600 45 23-Jan-99 779 3600 55 1236 3500 0 0 52 59 37 3600 60 463 3600 251 1100 3600 3450 0 0 0 519 3600 50 24-Jan-99 771 3600 55 1235 3500 0 0 52 58 38 3600 60 453 3600 251 1087 3600 3450 0 0 0 501 3600 60 25-Jan-99 786 3600 55 1247 3500 0 0 52 58 36 3600 65 445 3600 25 1105 3600 3450 0 0 0 518 3600 55 26-Jan-99 780 3600 55 1237 3500 01 0 52 57 41 3600 65 452 3600 25 1099 3600 3450 0 0 0 520 3600 50 27-Jan-99 785 3600 55 1250 3500 0~ 0 52 58 40 3600 65 456 3600 25 1103 3600 3450 0 0 0 519 3600 55 28-Jan-99 783 3600 60 1229 3500 0 0 52 58 47 3600 60 450 3600 25 1094 3600 3575 0 0 0 518 3600 50 29-Jan-99 796 3600 60 1245 3500 0 0 52 58 47 3600 60i 460 3600 25 1108 3600 3450 0 0 0 536 3600 50 30-Jan-99 792 3600 60 1243 3500 0 0 52 58 52 3600 60: 460 3600 25 1107 3600 3450 0 0 0 530 3600 50 3 l-Jan-99 813 3600 60 1262 3500 0 0 52 58 52 3600 60 472 3600 25 1128 3600 3450 0 0 0 560 3600 50 TOTAL 24,094 38,724 0 1,249 14,190 34,259 0 15,911 MAXIMUM 3,600 60 3,600 0 52 62 3,600 65 3,600 50 3,600 3,575 0 0 3,600 80 AVERAGE 777 3,600 51 1,249 3,524 0 0 51 59 40 3,600 60 458 3,600 30 1,105 3,600 3,428 0 0 0 513 3,600 51 # DAYS 31 31 0 31 31 31 0 31 02/10/99 · Aschor'af!e, DISPOSAL WELL M~ch-99 A34-14 A4 IA-I ILN A44-11 Al 1-13R2 Al 1-12 A23-0 IR A12-12 A33-14 ~i~E~ii!iiiiiiiiii! INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INJ ANNU 01-M~-99 811 3600 50 1239 3550 0 0 50 63 54 3600 70 466 3600 50 1114 3650 3500 0 0 0 558 3600 50 02-M~-99 813 3600 50 1247 3550~ 0 50 63 44 3600 70i 468 3600 50 1119 3650 3500 0 0 0 556 3600 50 03-M~-99 801 3600 50 1225 3550 0 50 63 45 3600 70 459 3600 50 1098 3650 3500 0 0 0 549 3600 60 04-M~-99 806 3600 55 1231 3550 0i 0 50 63 50 3600 70 462 3600 40 1110 3600 3475 0 0 0 554 3600 50 05-M~-99 806 3600 60 1229 3550 0 0 50 64 59 3600 70 456 3600 25 1108 3600 3450 0 0 0 556 3600 50 06-M~-99 811 3600 60 1236 35500 0 50 62 59 3600 70 457 3600 50 1111 3600 3500 0 0 0 558 3600 50 07-M~-99 848 3600 55 1269 3550 0! 0 50 62 58 3600 70 488 3600 50 1147 3600 3500 0 0 0 600 3600 35 08-M~-99 821 3600 60 1223 3550 0i 0 50 64 60 3600 70 477 3600 50 1112 3600 3500 0 0 0 578 3600 40 09-M~-99 846 3600 55 1252 3550 0 0 50 63 60 3600 70 492 3600 50 1140 3600 3500 0 0 0 604 3600 35 10-M~-99 839 3600 55 1255 3550 01 0 50 63 61 3600 70 489 3600 50 1138 3600 3500 0 0 0 595 3600 40 11-M~-99 806 3600 55 1231 3550 01 0 50 63 50 3600 70 462 3600 40 1110 3600 3475 0 0 0 554 3600 50 12-M~-99 815 3600 50 1235 3550 0 0 50 64 58 3600 70 472 3600 50 1112 3600 3500 0 0 0 560 3600 65 13-M~-99 820 3600 50 1232 3550 0 0 50 65 53 3600 70 471 3600 50 1113 3600 3500 0 0 0 567 3600 65 14-M~-99 819 3600 50 1230 3550 0! 0 50 66 61 3600 70 470 3600 50 1106 3600 3500 0 0 0 563 3600 60 15-M~-99 818 3600 50 1244 3550 0i 0 50 64 58 3600 70 476 3600 50 1119 3600 3500 0 0 0 574 3600 60 16-M~-99 816 3600 50 1215 3550 0 0 50 66 52 3600 70 466 3600 50 1099 3600 3500 0 0 0 564 3600 60 17-M~-99 819 3600 50 1217 3550 0 0 50 63 56 3600 70 470 3600 50 1116 3600 3500 0 0 0 579 3600 50 18-M~-99 837 3600 50 1240 3550 0 0 50 60 61 3600 65 482 3600 50 1133 3600 3500 0 0 0 590 3600 45 19-M~-99 808 3600 55 1207 3550 0 0 50 62 62 3600 65 463 3600 50 1097 3600 3500 0 0 0 561 3600 55 20-M~-99 813 3600 55 1219 3550 0 0 50 62 58 3600 65 466 3600 50 1106 3600 3500 0 0 0 559 3600 60 21-M~-99 806 3600 55 1207 3550 0 0 50 62 53 3600 65 461 3600 50 1095 3600 3500 0 0 0 558 3600 60 22-M~-99 818 3600 55 1222 3550 0 0 '50 62 55 3600 65 468 3600 50 1110 3600 3500 0 0 0 571 3600 60 23-M~-99 806 3600 55 1206 3550 0 0 50 63 57 3600 65 464 3600 50 1093 3600 3500 0 0 0 560 3600 65 24-M~-99 822 3600 55 1228 3550 0 0 50 64 54 3600 70 472 3600 50 1113 3600 3500 0 0 0 574 3600 65 25-M~-99 809 3700 60 1217 3700 0 0 50 67 61 3700 70 462 3700 50 1098 3700 3495 0 0 0 560 3700 65 26-M~-99 811 3600 55 1215 3550 0 0 55 64 55 3650 70 461 3600 50 1097 3650 3495 0 0 0 562 3600 65 27-M~-99 810 3600 60 1214 3550 0 0 52 66 52 3625 70 459 3600 50 1098 3650 3490 0 0 0 565 3600 28-M~-99 815 3600 55 1220 3550 0 0 55 65 52 3625 70 461 3600 50 1103 3650 3500 0 0 0 574 3600 55 29-M~-99 813 3600 60 1217 3550 0 0 55 62 55 3625 65 460 3600 50 1101 3650 3495 0 0 0 572 3600 55 30-M~-99 814 3600 55 1218 3550 0 0 55 65 52 3625 70 460 3600 50 1103 3650 3495 0 0 0 574 3600 55 31-M~-99 816 3600 55 1225 3550 0 0 55 67 52 3625 701 460 3600 50 1104 3650 3495 0 0 0 572 3600 5¢ TOTAL 25,313 38,065 0 1,717 14,500 34,423 0 17,621 MAXIMUM 3,700 60 3,700 0 55 67 3,700 70 3,700 50 3,700 3,500 0 0 3,700 65i AVERAGE 817 3,603 54 1,228 3,555 0 0 51 64 55 3,609 69 468 3,603 49 1,110 3,618 3,496 0 0 0 568 3,603 54 # DAYS 31 31 0 31 31 31 0 31 04~8~9 CANNE! ! 9 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown-- Stimulate Plugging-- Perforate~ Pull tubing After casing__ Repairwell~ Other X 2. Nameof~pe,rator uross Ilmoers Operatinq Company 3. Address 210 Park Ave.,Suite 2350 Okla. City, 0K.73142 5. Type of Well: Development __ Exploratory ~ Stratigraphic I Service X 4. Location of well at surface Leg 2, Cond. 12,1677' FSL&367' FEL Sec. 11,T8N, R13W, SM At top of productive interval 10,530' MD,947'FSL & 238'FWL SEC. 11,T8N,R13W, SM. At effective depth At total depth @12,047' MD, 2057' FSL & 235' FWL Sec.ll,T8N,R13W,SM 6. Datum elevation (DF or KB) 116' KB 7. Unit or Property name Hiddle (;round Shoal feet 8. Well number A41A- 11LN 9. Permit number/approval number 195-119 10. APl number 50- 733-20179-03 11. Field/Pool HG$ "G" Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12,047' feet 10,045' feet 11,950' feet 9,983' feet Plugs (measured) Junk(measured) MOTER & MILL @ 10,990' Casing Length Structural Conductor 330' Surface 1990' Intermediate 7,765' Production 5089' Liner 1365' Perforation depth: measured Size Cemented Measured depth True vertical depth 20" 13-3/8" 810 sx 0-1990' 0-1934' 7" 824 sx 0-7765' 0-7151' 5" '660 sx 5654'-10743' 5121'-9196' 3-1/2" SLOT. LINED 10680'-12045' 9150' - 10,045' 5" 10,530' - 10,666' true vertical 5" 9,041' - 9,173' Tubing (size, grade, and measured depth) 2-7/8",6.5~,L-80 EUE@ 5,520' & 2-3/8" 4.7# L-80 @8,515' Packers and SSSV (~pe and measured depth) Baker "DB" PERHANENT PKR @ 8,430'. 13. Stimulation or cement squeeze summary Intervals treated (measured) 9041' - 9173' & 10530'-10666' Treatment description including volumes used and final pressure Clean out/w 836gal 7-1/2~ HCL & N2 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Prior to well operation 778 70 Subsequent to operation 564 73 Tubing pressure 3625 3625 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil_ Gas Suspended_ Service X 17. I hereby certify that the for.~ing is true and correct to the best of my knowledge. Signed Title Sr. Engineering Tech Date 05/14/01 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE DAILY OPERATIONS REPORT WESTERN DISTRICT WELL NAME: MGS A41A-11LN AFE #: 100436 ESTINLATED TD: PBTD: COUNTY/STATE: Cook Inlet, ACCOUNTING #: 62215 CLASSIFICATION: CTU CLEANOUT OF SCALE AND ACID WASH DESCRIPTION: SECTION CONTRACTOR: CONTRACTOR: XTO PLATFORM C OPERATOR: CROSS TIMBERS OPEP~ATING COMPANY o4/o5/oi 04/06/0i 04/07/01 04/08/01 04/09/01 FIRST REPORT. Objective: CTU Cleanout and Acid Wash. Date First Report: 04/05/01. Rig up CTU and pressure test all lines and equipment to 3000#'s. Hold prejob safety meeting. RIH with coiled tubing. Pumped FIW at 1 BPM while running in hole. Sat down with coil tubing at 10886. Worked for 30 minutes. Could not get any deeper with mud motor with a scale mill while pumping with friction reducer. POOH with coil tubing. Change bit on mud motor to a tapered mill. Shut-down for evening at 10:30pm. DCC: $24,465 CCC: $24,465 RIH with coil tubing with tapered mill (1.778). Stopped at 8230. POOH to 8200. Worked coil from 8200 to 8537. Made 2 trips. RIH and stopped at 10886. Milled for 1 hour. Did not make any hole. POOH with coil. The bottom of the Mill looked like we were milling on metal. Change to a rotating type nozzle (1.74). RU coil and pressure test to 3000#'s. RIH and stopped at 10886. POOH to 10885. Squeeze 500 gal of 7-1/2% of HCL acid at 1 BPM. Maximum pressure was 2780#'s. Let well soak for 30 minutes. POOH to 10530. RIH and washed across perfs at 1 BPM With 336 gals of 7-1/2% HCL acid from 10530 to 10880. POOH with coil. Took acid Returns to 250BBL on deck tank. Approximately 100 BBL'S to tank. RD CTU. DCC: $35,495 CCC: $59,960 Inject 382 BLWPD @ 3600#. Inject 413 BLWPD @ 3600#. Inject 397 BLWPD @ 3600#. DAILY OPERATIONS REPORT WESTERN DISTRICT WELL NAME: MGS A41A-11LN AFE #: 100436 ESTIMLATED TD: PBTD: COUNTY/STATE: Cook Inlet, AK ACCOUNTING #: 62215 CLASSIFICATION: CTU CLEANOUT OF SCALE AND ACID WASH DESCRIPTION: SECTION CONTRACTOR: CONTRACTOR: XTO PLATFORM C OPERATOR: CROSS TIMBERS OPERATING COMPANY 04/iO/Oi 04/ii/oi 04/12/01 DCC: $-0- 04/i3/0i DCC: $-0- o4/i4/oi o4/i5/0i o4/i6/oi o4/i7/oi o4/iS/oi Inject 385 BWPD @ 3600#. DCC: $-0- CCC: $59,960 Inject 374 BWPD @ 3625#. DCC: $-0- CCC: $59,960 Inject 651 BWPD @ 3650#. Back flw for 3 hrs. TP drop'd to 1100#. No est'd rcvry. CCC: $59,960 Inject 300 BWPD @ 3650#. Back flw for 2 hrs. Inj rate increased from 14 to 18 GPH. CCC: $59,960 Inject 344 BWPD @ 3650#. Back flw 4 hrs. Didn't help. DCC: $-0- CCC: $59,960 Inject 370 BWPD @ 3650#. DCC: $-0- CCC: $59,960 Inject 257 BWPD @ 3650#. WL 1.70" GR run on injector. Tag fill 10793 KB. SI for 6 hrs. DCC: $-0- CCC: $59,960 Inject 305 BWPD @ 3650#. DCC: $-0- CCC: $59,960 Inject 308 BWPD @ 3650#. DCC: $-0- CCC: $59,960 TEMPORARILY DROP UNTIL FURTHER ACTIVITY DAILY OPERATIONS REPORT WESTERN DISTRICT WELL NAME: MGS A41A-11LN AFE #: 100436 ESTIPLATED TD: PBTD: COUNTY/STATE: Cook Inlet, AK ACCOUNTING #: 62215 CLASSIFICATION: CTU CLEANOUT OF SCALE AND ACID WASH DESCRIPTION: SECTION CONTRACTOR: CONTRACTOR: XTO PLATFORM C OPERATOR: CROSS TIMBERS OPERATING COMPANY 04/27/01 04/28/01 04/29/01 04/30/01 RETURN TO REPORT. Objective: CTU Cleanout and Acid Wash. Date First Report: 04/05/01. Start rigging up Coil Tubing Unit. Secure well for evening. DCC: $10,586 CCC: $10,586 Continue rigging up coil tubing. Pressure test all line and equipment to 3000#'s. Hold safety meeting. RIH with 1-1/2" coil tubing with motor and straight mill (1.78) while pumping at 1.1 bpm of FIW. Stopped at 10764. TOok 10 minutes to work through tight sport. RIH and stopped at 10857. Took 10 minutes to get through tight spot. RIH and stopped at 10888. Took 15 minutes to get through tight spot. RIH and stopped at 11016. Went through tight spot and stopped at 11175. Took 5 minutes to get through tight spot. RIH and stopped at 11189. Pumped 5bbl sweep of Flovis atl bpm of FIW. POOH to follow Flovis. Stopped at 11011. Worked CTU for 5 hours by pumping N2, FIW and Flovis sweeps. Tried various rates and pressures. Move coil up to 10990, but could not get any further up hole. Dropped .50 ball to unlatch from motor and mill. When ball hit disconnect the coil started moving down the holeo Pooh with CTU. Had 1 tight spot at 10857-stuck for 10 min and worked free.. Tools left on hole were as follows: GS fishing neck, BOT mach 1 motor, Crossover, BOT bladed junk mill. Length of tools were 10.47' and the max OD was 1.78. DCC: $ 42,051 CCC: $52,637 Start injection 18:30. Inj 630 BW @ 3600#. DCC: $40,454.00 CCC: $93,091 At 0600 hrs inj rate 22.7 BPH. DCC: -0- CCC: $93,091 DAILY OPERATIONS REPORT WESTERN DISTRICT WELL NAME' MGS A41A-11LN AFE #' 100436 ESTIMATED TD' PBTD' COUNTY/STATE' Cook Inlet, AK ACCOUNTING #' 62215 CLASSIFICATION' CTU CLEANOUT OF SCALE AND ACID WASH WORK ACCOMPLISHED: CTU CLEAN OUT AND ACID WATCH DESCRIPTION' SECTION CONTRACTOR' CONTRACTOR' XTO PLATFORM C OPERATOR' CROSS TIMBERS OPERATING COMPANY o5/oi/oi Inject 24 hrs. 581 BWPD @ 3625 psi. DCC' -0- CCC' $93,091 05/02/01 Inject 24 hrs. 564 BWPD @ 3625 psi. DCC' -0- CCC' $93,091 FINAL REPORT 13:44 14052325778 C IUrj UKL; STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: AbsndOfl ~ 9USpet~d ~ Operetlol~ Shutdown _ Re-enter ~uapended well .~ At, er casing ~ Repair well .. Plugging Time extension .~ Stimulate_.. C~ange approved program ._ PUll tubi,ng Vartalce ~ Per/orate @Ihs: 2. Name of Operator Crps$ Timbers Operating Cqmpany 3. Addresm 2350 P/bRK AVE, SUITE 2350 OKLA. CITY, OK. 73102 - 4. Location of well at surface "A",Leg 2,Cond. 12. 1677' FSL & 367' FEL Sec. 11,TSN,R13W,S.M, At top of productive interval 10,530' ~lD, 947'FSL & 238'FWL Sec. 11,T8N,R13W,S. At effective depth 5. Type of Well: Development X_ Exploratory Stratlgraphlo ~ Service At total depth 12,047' HD, 2057' FSL & 235' FWL off Sec. 11,TSN,R13W,S.M_ 6. Datum elevation (DF or KB) 116' KB 7, Unit or Property name Middle Ground Shoal Well number A41A- 11 LN 9. Permit number 195-119 w' 10. APl number 50- 733-20179-03 '11. Field/Pool MGS/"G" Pool 1£, Present well condition ~urnmary Total depth: measured true Vertical 12,047 feet ~, P[uga (measured) 10,045 feet ' ' Effective depth: meaeured 11. 950 feet Junk (measured) fi"de vertical 9983 feet feet Casing Length Size Cemented StructuraI Conductor 330' 20" Surface 1990' 13-3/8" 810 sx ~ ~,~7765' 7" 824 sx Production~ 5089 5" 660 SX Liner ~=-~,~ 1365 3-1/2" SLOTTED LINER Perforation depth: measured 5" - 10,530' to 10,666' true vertical 5" - 9,041' to 9,173' Measured depth 0-1990' 0-776B' 5654'-10743' 10680'-12045' Tubing (size, grade, and measured depth) 2-7/8",6.5~,L-80 EUE 0 5520' and 2.3/8" 4,7# L80 @8,515' Paoker~ ~nd sSSVBAKER ~,t~e, and measured d¢l~h)~ PERMANENT 8430'. True vertical depth 0-1934' 0-71~1' 5121' - 9196' 9150'- 10045' 1~. Attachments Description summary of proposal Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 04/02/2001 Name of approveP" - ¢ ,,.~,,,"'~ Date approved lB. Status of well classification as: ~Oil X Gas ~ Service Suspended Title SR, ENGINEERING TECH 03/28/2001 FOR COMMISSION USE ONLY Conditions of approval: Notify Commi~,lol~i~ representative may witne~ Plug integrity BOP Teat ~ Location clearance Mechanical Integrity To,t__ Subs,quant form required Approved by order of the Commission Form 10-403 Rev 06/15/88 -'~,~t~ir~-~AL SIGNED B"/ '' 'r~V!Or Seamount CONTACT CHARLES POPE @"(405) 319'321I Commissioner SUBMIT IN~T~IIP LICATE ORIGINAL 13:44 CROSS TINIBERS OPERATING COMPANY MGS A41A-11LN COOK INLET, ALASKA WELL DATA SURFACE CASING: PRODUCTION CASING: L~[NER: LINER: TI.rBING: PERFORATIONS: OBJECTIVE: 13 3/8" 61# K55. Set ~ 1990:. Cmt'd wi 810 sx. 7" 26, 29# N80, Set at 7765'. Cmt'd w~ 824 sx. 5" 18 # Pll0 STL, TOL ~ 5654'. Set ~ 10743:. Cmt'd w/560 sx, 3, 1/2'" 9.3# J55 BTC. TOL ~ 0'. Set ~ 12045', Slotted. 2 7/8" 6.5# L80 8R EUE Used ~ 5520' and 2 3/8" 4.7# L80 8R EUE ~ 8515'. HZ-HR 10530-10666' Slotted 10680-12045' Cleanout scale w/CTU and Acid , RU CTU, NU BOPs a~d test to 3000 ps/. RIH w/mill and motor on 1 ½" CT to PBTD while circ FiW, Circ clean. POOH, RIH w~ jet blasting tool. Wash all tire spots w/7 55% HCI. Continue in hole to top of slotted liner at 10680:. Wash slots w/2000 gal of 7 [4% HC1, Circ out acid, Do not pump into formation. POOH, Monitor well for H2$. POOH and RD CTU, Have H2S scavenger on location and pump into returns as needed, 3. Back flow well for 300 bbls or until returns clean up and H2S drops to 0 ppm. ORIGINAL Cross Timbers orating Company Present Completion MGS A41A-tl LN WIW Cook Inlet, Alaska Leg 2, Conductor 12 APl No.: Spud: 20" Conductor Csg @ 330' Surf Csg: 13 3/8", 61 lb, K55. Set @ 1990', Cm'('d w/ Prod Csg: 7", 26-29 lb, N80, Set @ 7765'. Cmt'd w/ KB' ~ Water Depth; Tbg: 2 7/8", 6.5#, LB0 8rd, EUE used & 2 3/8", 4.7f¢, L80 8rd EUE new tbg X-over from 2 7/8' to 2 3/8" @ 5520' "X" Profile Nipple @ 340' GLM MD-TVD Port Ptro Psc Pso 1 1947' 189,~' ALL 885 950 2 3726' 3519' DUMMY 867 91~ 3 5098' 4724' GAS 829 904 4 6208' 5709' LIFT 811 870 5 7094' 6521' VALVES 79-1 834 6 7734' 7122' 766 82§ 7 8346' 7612' (3 - 2 7/8" D-SO amd 4 - 2 3/8" U-SO 8rd EUE GLM's) 1 Jt Tbg Otis "X" Nipp]e (~ 8391' (ID of 1,876") I Jt, tbg Baker "DB" Permanent Pa~ker ~ 8430' 15' Sealbore Extension w/15' seals inside Otis "XN" Nipple @ 8482' (ID of 1.79'1") 1 Jr, tb9 Bottom of wireltne re-entry guide @ 8515' TOL (~ 5624' (liner top isolation packer) Liner Csg: 5", 18 lb, P110 STL. Set @ 10743'. Cmt w/ Peris fn 7" isolated behind 5" liner: AS 6084'-6136' FL(l); 6~74'-6638' FL(2): 6659'-6677' FP; 6746L6772' FS(1): 6846'-6867' FS(2): 6870'-6881' GB(1): 7157'-7230' GB(2) 7251'-7289' Peris in $" Liner: HZ-HR: 10530'-10743' 3 1/2", 9.3#, J55 BTC slotted liner 10680-12045'. (Liner has special clearance couplings). PBTD: ' TD: 12,047' ORIGINAL PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS Page' i Date' 07/28/97 RUN DATE_RECVD 95-119 95-119 95-119 FORMATION DGR/EWR4 -MD DGR/EWR4-TVD L.~0749-11744 ~51-8835 10/26/95 10/26/95 10/26/95 95-119 IND RE S/GR 10-407 ~3~10743-11734 ~COMPLETION DATE 10/25/95 DAILY WELL OPS ~'/~/~ ~ /~]Y TO [~/~)/~17 Are dry ditch samples required? yes ~~nd received? Was the well cored? Are well tests required? ,/es Well is in compliance Initial COMMENTS yes ~_~Analysis & description received? ~_Received? yea_--no J Jan-30-97 08:51A Shell PlatfomA 9O7 776 2522 P.02 SHELL WESTERN E7P INC. PLATFORM "A" HCOI BOX 485 OLD WIK RD. KENAI, ALASKA ALASKA OIL 7 GAS CONSERVATION COMMISSION ATTN: BLAIRE WONDZELL 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501 Blake, on 01/29/97 a MIT was performed on A41A-11. The annulus was pressured to 2100 PSI, in 45 minutes the pressure dropped to 2010 PSI. The last 30 minutes of the test the pressure dropped to 1990 PS1. Per State requirements the well has passed the MIT. If there are any questions please don't hesitate to call Tom Reese or Doug Marshall at 907-776-2506. Sincerely, 1Ma~ha[l Tom Reese Doug RECEIVED JAN Oil & (]aS Oon$. OommJssion Anchorage January 10, 1997 Shell Western E&P Inc. An affiliate of Shell Oil Company HCO1 Box 485 Kenai, AK 99611 (907) 776-2511 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ORIGINAL SUBJECT: SUBMISSION OF FORM 10-404 REPORT OF SUNDRY WELL OPERATIONS TO CONVERT MIDDLE GROUND SHOAL WELL NO. A4 IA- 11LN. Enclosed in triplicate is the Report of Sundry Well Operations, Form 10-404, to convert MGS A41A-11LN to a water injector. Operations are expected to begin January 15, 1997. Once the operation has been completed, we will be submitting a follow-up 10-404 detailing the representative daily average injection data (subsequent to operation). Attached you will also find a copy of the current well bore diagram, the CTI procedure, CTI parts list and a copy of the 10-403 which was originally submitted for this well on October 4, 1995. Our personnel have been instructed that they will need to have an AOGCC representative present for the MIT test and will be planning accordingly. If you have any questions or require further data, please don't hesitate to call me at (907) 776-2511. Thank you! Sincerely, William A. Miller Unit Office Supervisor JAN 1 ~ 1997 Oil & G~ C~n$, Commi~ion Anchorage Attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing After casing Plugging Perforate~ Repair well~ Other X 2. Name of Operator Shell Western £&P Inc. 3. Address HC01 Box 485 01d Wik Road Kenai 99611 5. Type of Well: Development Exploratory Stratigraphic Service -X-- 4. Location of well at surface "A",Leg 2,Cond 12: At top of productive interval 1677' FSL&367' FEL, S 11, T8N, R13W, S. H. 6. Datum elevation (DF or KB) ]1_6' i(R feet 7. Unit or Property name Middle Ground Shoal 8. Well number A41A-11LN 9. Permit number/approval number 10,530'HD: 947'FSL&238'FWL, Sll, T8N, R13W, S.H. At effective depth At total depth 12,047'HD: 2057'FSL&235'FWL, Sll, T8N, R13W, S.H. 95-119/95-177 10. APl number 50- 733-20179-03 11. Field/Pool Mi ddle Ground Shoal 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12,047 feet Plugs (measured) 10,045 feet 11,950 feet Junk (measured) 9983 feet ORIGINAL Casing Structural Conductor 330 ' Surface 1990' ~.t=..-=.=d~ct= ~.....~7765' Production ~--"~--___...~,. 508g' Liner ~ ~ 1365' Perforation depth: measured Length Size Cemented Measured depth 20" 13-3/8" 810 sx 0' - 1990' 7" 824 sx 0' - 7765' 5" 560 sx 5654'-10743' 3-1/2" Slotted Lnr 10680'-12045 7" - 6084' to 7289' and 5" - 10530' to 10666' true vertical True vertical depth O' - 1934' O' - 7151' 5121'-9196' 9150'-10045' 7" - 5606' to 6615' and 5"- 9041' to 9173' Tubing (size, grade, and measured depth) 2-7/8" 6.5#,L.-80 8rd EUE used tbg & 2-3/8" Packers and SSSV (type and measured depth) Baker "DB" Permanent, Packer (~ 8430' 4.7# L-80 8rd EUE new tbg 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure JAN 1 b 1997 Oil & Ggs Cons. Cornmi~n Anchorage 14. Pdor to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure 200 110 2 68 90 To be reported after the well ~s CTI on 1/15/97. 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations~ 16. Status of well classification as: Oil Gas~ Suspended Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,~~ ~,/~, Title Form 10-404 Rev O6/15/88 -44 - Date 01/10/97 SUBMIT IN DUPLICATE Top of 3 1/2" 1 iner 0 10,680' 2 3 X X < X < / \ I I' I ID : 12047' MIDDLE GROUND SHOAL No. A41A-11LN COMPLETION EQUIPMENT DETAIL (11/22/95) I .L 20" Conductor Casing @ 330' - "X" Profile Nipple @ 340' 13-3/8" 61# K-55 Surface Casing @ 1990' .... 2-7/8" 6.5# L-80 8rd EUE used tubing and 2-3/8" 4.7# L-80 8rd EUE new tubing (2-7/8" on top w/X-over to 2-3/8" g 5520') GLM MD 1 1947 2 3726 3 5096 4 6208 5 7094 6 7734 7 8346 -TVD PORT Ptro Psc Ps@ GAS 1895 12 925 885 950 --- 3519 12 910 867 916 --- 4724 16 950 829 904 --- 5709 16 935 811 870 --- 6521 16 920 791 834 --- 7122 20 1005 766 825 --- 7612 5/16" ORIFICE (3 - 2 7/8" D-SO and 4 - 2 3/8" U-SO 8rd EUE GLM's) < ....Top of 5" liner @ 5654' (liner top isolation pkr) Perfs in 7" isolated behind 5" liner : AS 6084-6136' FS(1) 6845-6857' : FL(l) 6574-6638' FS(2) 6870-6881' = FL(2) 6659-6677' GB(1) 7157-7230' : FP 6746-6772' GB(2) 7251-7289' _~ 7" 26-29# N-80 @ 7765' GLM #7 @ 8346' 1 jt 2-3/8" 4.7# L-80 8rd EUE tubing OTIS "X" Nipple @ 8391' (ID of 1.875") 1 jt 2-3/8" 4.7# L-80 8rd EUE tubing BAKER "DB" Permanent Packer @ 8430' 15' sealbore extension w/15' seals inside 1 jt 2-3/8" 4.7# L-80 8rd EUE tubing OTIS "XN" Nipple @ 8482' (ID of 1.791") I jt 2-3/8" 4.7# L-80 8rd EUE tubing Bottom of wireline re-entry guide ~ 8515' Perfs in 5" liner .... HZ-HR 10530' - 1066~-~I.~-~-:,~ ¥'~''''~t 7~. ~,-.~m~ 5" 18# P-110 STL liner @ 107,4j.'~'N ! 5 !997 3 1/2" 9.3# J-55 BTC slotted liner @ 12045' {liner has special clearance couplings) C: \F I LES\PROG\A41-Al 1L3. WBD CONVERT TO INJECTOm PLATFORM A A41A-11LN PRESENT STATUS: PRODUCER Well is currently producing 202 BOP/D. See Attachment #1 for current completion diagram. There are 7 gas-lift mandrells, currently lifting at #7 gas-lift orifice. There is no SSSV in well. OBJECTIVE: CONVERT WELL TO INJECTOR 1) Change 7 gas-lift valves. Pull 7 gas-lift valves and run 7 dummy gas-lift valves. 2) Set pxn plug to test tubing and to circulate through #7 gas-lift mandrell. 3) Circulate 200 BBL'S with 20 gal's of Nalco inhibitor into casing. 4) Change production line to injection line. PROPOSED OPERATIONS: WIRELINE AND WELDING NOTE: DO NOT PROCEDE ANY FURTHER UNLESS WIRELINE OPERATOR, WELDER. AND ALL EQUIPMENT IS ON LOCATION. WIRELINE: 1) Run 1.875 gauge ring and tag xn nipple at 8,~82 2) Pull 7 gas-lift valves. 3) Repair 7 gas-lift latches 4) Run 6 Dummy gas-lift valves. Leave bottom gas-~ifi mandrell open. 5) Run Otis 1.875 PXN Plug with 1.79 No-Go. Set ~lt.~g. i;~, XN Nipple at 8482 (md). 6) Circulate 200BBL's of FIW with 20 gai's of Naico inhibitor followed by 60 BBL's of FIW. a. Casing volume is 200 BBL's. b. Tubing volume is 60 BBL's. 7) Run #7 Dummy gas-lift valve. Test tubing to iniection pressure. Observe casing pressure for 1 hour. If no build-up procede with procedure. !f c.3sing pressure rises during testing pull and check all 7 gas-lift valves and retest. 8) Pull PXN Plug from XN nipple at 8482 ,,md;. WELDING: 1) Rebuild Waterf!ood Injection Header in V;./e!ihead ??2 while wirelining is going on. 2) Fabricate as much of injection header as possible i~ ',ye!ding shop. 3) Pressure test all lines from injection header ~o ,:.:asi~*,:.~ -.valve. PUT WELL ON INJECTION. Recommended: Approved: iDate: cc: Maurice Dunckley Shane Alexander Bill Miller Larry Little CONVERT TO iNJECTioN A41A-11LN PARTS LiST ~ ON NEED TO DESCRIPTION ! LOCATION .ORDERED ORDER ITEiVI ~ WIRELINE 1 IPXN LOCK t 1 3 DUMMY VALVES , GAS-LIFT 9 ! 12/3O/96 4 iGAS-LIFT VALVE PACKING ! SURFACE EQUIPIVlENT 1 INJECTION RUN i 12/31/96 2 TURBINE METER ~ 5 3 NATIONAL VALVE ;~ 2 4 NATIONAL CHOKE WITH CHECK VALVE 5 O-RINGS (FOR LEAKS) ~ 12/31/96 6 FLANGE RINGS '.~ I 6 7 iBLIND FLANGE (G/L HEADER) ~ i 8 ~BLIND FLANGE (PROD HEADER) ' i 9"!BLIND FLANGE W/BLEEDER (C~SI,AG)~' i 10 IGASKETSiRINGS FOR BLIND FLANGES i 3 11 i,.~RAY-LOC HUBS , 2 r 12 ~20 GAL. OF NALCO INHIBITOR · , 12130196 i WELDING EQU,P~,,,,Er~ -~ 1 ~,SCHEDULE 160 PIPE '~:0' .- S~FOR 160 PIPE~ 2 iL' ? 3 ~R-=4 FLANGE W/WELDING END : ? 4 !NAT. FLANGE W/WELDING END i I . Il I jAN 1;5 199'7 STATE OF ALASI'v. ALASKA OIL AND C-.-.-.-~S CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type ot Request: AI3anOon After casmng Change &opro,,m~l progr_.~m 2. Name of Operator Shell Western E&P linc, Repair well Ooeratmn sl~rtclovm Re-enter muapen(led wM 130 Trading Bay, #310 Kenai, AK 99611 PlUgging Time exten~on Pull tubing Variance Perforat, 5. Type of W~I: StratigraCm~ _.._ Sm-V.=e X 4. Location of welt at surface Platform 'A', Le92. Cond 12: 1677'FSL & 367'FEL, $11, T8N, RZ3N, SH At top of prodtx3tNe mteeval 8500'MD: 4820'FSL & 368'FEL, S11, T8N, R13W, SM At effective deO~ At total 12170'ND= 2174'FSL & 4907'FEL. 51. T8N, R13W, Phugs (measured) Jun~ (measure) 12. Present we~ concliUoa suma~ Tota ~U~ memume 7765 feet t~ ~ 7151 ~' m~e=~ed 7360 fee, true veruca 6770 feet Stimu{ate 6. Datum emva~on (c~' ~ ) 116' ~ Middle Gro~d S~al 8. W~~ ~-11~ 9. P~ n~ 95-119 10. APl num~ ~' 733-20179-~3 1. F~/P~ Htddle ~o~ S~ai feet Casing Leng~ Structural co~uctor 330' sumac, 1990' (nterrnecl~te ProductlOrl 7765' L. iner Pertoratton depth: meesure(I 20' 13-3/8' m 6084' true vertic~ 5597' Tub,rig (size. gr~ee, and measured Size Cementecl Measured cleOU3 True vertk3M deDt~ 810 sx 1990' 1934' 7289' 824 sx 7765' 7151' cL) 0CT 0 9 1995 6703' ,N~ 0il & Gas Cons. Commission Anchorage Tubing & packer not yet set as well is drilling aC 10,743'. Well is permitted as water injector. Request permtsa, to~n~,to produce for approximately 3 - 6 months PackemarmSSSV(W~eandmeasured~e~th) will file a 10-404 to cease production a~d~tn injection. 13. ~ ttacnments Deacflgtion summary of prol:~al X Detmled ol3erationa program 14. Estimated ~late f(x ~ o¢~&t~ October' 24, 1995 16 If prol:x3sm was verDally a,oproved Nar~ of approver 17. I hereOy certify ~flqat ~ fore~M~g m .true.an~ correct to tlqe bast of my Imowledge. Signed~... . Tit~e Sr. Production Engineer FOR COMMISSION USE ONLy .' Conclith3ns of approval: Notify Corrosion so representative r~y wtr~ Plug ~ntegnty BOP Test M~cllanCa~ '/77 Approved by orcler of tlqe Form 10-403 Rev O6/15/88 S~IN TRIPLICATE DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL No. A41A-11LN · A41A-11LN is currently being drilled. The drilling permit for this well was approved with the intent that this well would be an injector. That is still our ultimate intent. However, we are submitting this Application for Sundry Approvals (10403) to produce this well for a period of approximately 3-6 months prior to turning it into an injector. After completing the well, we will perform a no-flow test (based on expected reservoir pressures, the well should not flow). If the well does flow, we will install a storm choke in the "X" nipple (the "X" nipple will be mn at approximately 300'). The storm choke will save us the time and expense of running a SSSV on a well that will ultimately be an injector. It will also eliminate the use of a control line which w~ prefer not to have on an injector because of mechanical integrity concerns. When we are ready to begin water injection on A41A- 11LN, we will submit a Report of Sundry Operations (10404) indicating that we are done producing the well. We will then proceed to turn the xvell into an injector by inserting dummv valves in the gas lift mandrels and by removing the storm choke (if in fact it was necessary to install one). Please note that the attached 10403 contains the same information that was included in the drilling permit since drilling is still in progress. When filing the 10404 mentioned in the preceding paragraph, packer depth, tubing depth, actual total depth, etc.. will be included. (This same data will also be included when we file the Well Completion Report, Form 10407, after the well has been drilled and completed.) C:~files\sundry\4111 prod.doc -96 08:28A Shell Platfom A 907 776 Shell Western E&P Inc. An affiliate of ,~,hell Oil Company HCO1 Box 485 Old Wik Road Kenai, AK 99611-9704 (907) 776-5241 2522 P.02 January 30, 1996 State of Alaska Alaska Oil & Gas Consewation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Wondzell: SUBJECT: No-Flow Verification for A-41A-11LN On January 29, 1996 I witnessed a 'no-flow test on Shell Platform A, MGS A-41A-11LN (PTD 95-119). This welt was previously no-flowed on November 3, 1995 and witnessed by your inspector, John Spaulding. On November 21, 1995 we reperforated a small section of the Hemlock. We increased the flow of the well another 50 bbls, thus the reason for the retest. Gas-lift was shut off to well and well was depressured for 6 hours. The well was opened to separator with no pressure on well and for a period of 4 hours no fluid was produced. For a period of 2 hours no gas was produced. I believe this well Is not capable of non.assisted flow of hydrocarbons. If you have any questions regarding this report, please contact me on Platform A at (907) 776- 5241. Sincerely, "T, T. A. Reese Wireline Operator Alaska Operations dAN 30 1996 Alaska -96 08:28A Shell Platfom A 907 776 2522 P.01 Shell Western Platform "A" HCO1 Box 485 Old Wik Road Kenai, AK 99611-9704 E&P Inc. FAX TRANSMITTAL DATE: TIME; TO: NUMBER OF PAGES (Including Cover): "L.. Continental Division Western Asset Unit Phone (907) 776-5241 FAX (907) 776-2522 Centrex Fax 53515 (pause) 522. JAN 50 1996 /Saska Oil & Gas Cons. Commission Anchorage IF YOU HAVE PROBLEMS RECEIVING, PLEASE CALL (907) 776-5241 Shell Western E&P Inc. Tele¢opier Number: (907) 776-2522 Shell Western E&P Inc. An affiliate of Shell Oil Company P. O. Box 576 Houston, TX 77001 December 13, 1995 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 SUBJECT: SUBMITTAL OF WELL COMPLETION REPORT (FORM 10-407) for MIDDLE GROUND SHOAL A41A-11LN REFERENCE: APPROVAL NUMBERS 95-119 Enclosed are duplicate copies of the Well Completion Report (Form 10-407) for Middle Ground Shoal A41A-11LN. Reddlling operations were completed 10/23/95, the date of first production was 10/23/95, and the representative well test date was 11/23/95. As indicated in our Application for Sundry Approval (Form 10-403) dated 10/04/95, we are planning to produce A41A-11LN for approximately 3-6 months pdor to converting the well to injection service. If you have any questions or wish to discuss, please call Marcus Winder at 713~544- 3797 or Jeff Wahleithner at 713/544-3344. Sincerely, :~G. S. Nady, Manager Asset Administration - Western Asset Continental Division Enclosures WCPAOGCC.DOC- 1 STATE OF ALASKA : ,:, ,_~. ... A,_/~SKA OIL AND GAS CONSERVATION COMMISSION .._ :/~'~'~/~'~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~-,,:,~--- 1. Status of Well Classification of Service Well Shell Western E&P Inc. k-,'~-~i)zg,--~ 3. Address (.~CK 6265) 8. APi Nbdb¢%' ~, .', ~'~, ~' P.O. BOX 576, Houston, TX 77001-0576 so- 4. Location of w~l at sudace 9. Unit or Lease Nami~ ~ :~-~; PLATF A, LEG 2 , COND 12; 1677' FSL & 367' FEL Sll, T8N, R13W, S.H. HIDDLE GROUND :~i~IAL At Top Producing Interval 10. Well Number @ 10,530' MD-KB, 947' FSL & 238' FI~!L S1,. T8N, R13W, S.M. M~-11LN At Total depth 11. Field and Poc~ 12,047' MD, 2057' FSL & 235' ~L S1, T8N, R13W, S.N. 5. Elevation in feet (indicate KB,'E~% etc.) I 6. Lease Designation and Serial No. N~ "G' POOL 116' KBI ADL 18756 12_ [:)ate Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband 115. Water Depth, if offshoreI 16. No. of Completions I I 8-19-95 10-19-95 10-23-95 80 feetMSLI SINGLE 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set I21. Thickness of Pormafr°st 12,047' HD,~/o,o+S'~-vp . . - YES [] NO [] NONE teetMD NA 22_ Type Electric or Other Logs Run GR- F-NE_ ir RT-,] 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AM(~NT PULLED 5" 18¢ P-110,S95 5663' 10,743' 6" 560 SX - - - 3-1/2" 9.3i¢ ,]-55, NS0 10,680' 12,045' 4-1/8" SLOTTED I_NR - - - 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8", 2-~~ 8515' 8430' 10,530' - 10,666' (6 SPF) 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A I' 27. PRODOCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) lf)-?.3-9.~ f'-A.S I]FT Date of Test Hours Tested PRODUCTION FOR OIL-BE4_ GAS-MCF WATER-BBL CHOKE SIZE I GAS-OiL RATIO 11-23-95 24 TEST PERIOD 271 163 I 128/64"I 601 Flow Tubing Casing Pressure CALCULATED OIL-BE4_ GAS-MCF WATER-BBL OiL GRAVITY-APl Press. 95 670 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE ,~'..) :~;7., i!'- ":. il;-~; ~ ~.. .:,... % ,:~. ,.,.~ itt: ~-,. ...... ,.;, Form 10-407 Rev. 7-1-80 CONrl-INUED ~ REVERSE SIDE Submit in duplicate - 49 - G EOLC,:......~ARKERS ,...~..¢ FORMATION TESTS [ Include interval tested, pressure data, all fluids reoovered and gravity, GOR, NAME MEAS. DEPTH TRUE VERT. DEPTH and time of each phase. SEE ATTACHED GEOLOGIC HARKER SUMMARY 31. LIST OF ATTACHMENTS MORNING REPORTS. DIRECTIONAL SURVEY, GEOLOGIC HARKER SUMMARY 32_ I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ¢, ~]~~.~~6. S. ~Y T~ "~._ _ .~" - ASSET AD"I". Date 12/13/95 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1- Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21. Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Form 10-407 ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: WELLS R V PROG. DEPTH 12170 PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 WATER DEPTH 80 /GALLOWAY DR PRESENT ACTIVITY: PERFORMING RIG MOVE ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY 1 NLTA LTH/YTD ___/___ EST. DAY 45 LTA LTH/YTD ___/___ DAYS +/- DAYS SINCE LAST LTA 852 LAST BOP TEST ~~ LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED @ PP2 @ KILL SPEED @ SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 6.00 CLEARED PIPE RACK AND CUTTING OFF MARKER SUPPORTS FOR KATO. PERFORMING ~T__HE~JO~BS~_~UT~ES, AND STEPS IN THE MOVING OF THE RIG OVER LEG #2 AND RIGGING UP ON A41A-11LN. CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 6.00 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM m'A" WEll A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: WELLS R V SWEPI ALASKA DAILY DRILLING REPORT PROG. DEPTH 12170 PRESENT DEPTH FOOTAGE DRILLED SIZE OF lAST CSG 7.000 DEP. OF LAST CSG 7765 WATER DEPTH 80 PAGE 1 OF I ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA' ~ LAST BOP TEST LAST CSG TEST 2 45 PRESENT ACTIVITY: PERFORMING RIG MOVE /GALLOWAY DR BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED .... @ PP2 @ KILL SPEED SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 24.00 REROUTE KATO POWER CABLES AND ASSOCIATED LINES. WELD DOWN MARKER BRACES. MOVE AND SET PARTS HOUSE. SET CONNEX ON TOP OF PARTS HOUSE. SKID RIG TO EAST NEXT TO MUD DOCK. CLEAN MOON POOL DECK OVER LEG 1. BEGIN WORK ON HELIPORT. BEGIN DISCONNECTING LINES TO PUMP ROOM FOR REROUTING. BEGIN TO SKID RIG TO THE ~EST. CONTINUING RIG MOVE. T I ME .(H_R_~S~_. CUM. ROT. HRS ROTAT I NG .... MUD MOTOR TRIPPING .... c & c .... REAM I NG .... SURVEYS JET .... REPAIRS .... FISHING .... NIP UP/DOWN /BOP/WH .... TESTING BOP /WH .... RUNNING CASING .... CEMENTING .... PICKUP/LAY DOWN DS .... INSPECT BHA .... RIG UP/TEAR DOWN 2~.00_. WAIT ON WEATHER/MAT .... EVALUATION .... CORING .... JPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" UELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: MOVING RIG PROD. DEPTH 12170 ELEVAT. KB TO MSL PRESENT DEPTH DIST. KB TO BHF FOOTAGE DRILLED NLTA LTH/YTD SIZE OF LAST CSG 7.000 LTA LTH/YTD DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA MATER DEPTH 80 LAST BOP TEST 116.0 DATE 38.4 DAY 3 / EST. DAY 45 / DAYS +/- 854 LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED PP2 @ KILL SPEED SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 24.00 FINISHED SKIDDING RIG WEST. CLEANED UP O.D. MUD. REMOVED ESCAPE LADDER REMOVED HELIPORT BRACES [/_.N.E~T SIDE OF C~ INStALLeD PAD EYES ON THE BRACES. REINSTALLED BRACES ON EAST SIDE OF CAMP. REMOVED FLOW LINES FROM RIG TO PUMP ROOM AREA. REMOVED WIND BLOCK BETWEEN CAMP AND PUMP ROOM. MADE UP FLANGES ON FIRE WATER PUMP AND PIT SUCTION LINE. CLEAN UP WELDS ON SKID BEAMS. PREP DRAIN SYSTEM ON LEG 2 FOR RIG OPERATIONS. SPOT RIG IN PLACE TO TURN IT AROUND. PREP CAMP FOR MOVE AND MOVE CAMP. T I ME (ttRS2 ...... CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPA ! RS FISHING N!P UP/DOWN /BOP/WH TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS WELDER REBUILT 6" AUGER SYSTEM. PREP SLOPS TANK FOR MOVING [~WHR-2. RIG UP ,I/SHIP LITE WATER T/PIT #8. WELD DOWN SKID BEAM OVER WHR-2. INSTALLED ~IND BLOCK BACK ON'CAMP T_~U._MP ROOM. REMOVED SLOPS TANK [/W~R-2~_PR[P_~./~IN§TALL [N WHR-2. CONTINUING RIG MOVE AT RPT TIME. SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: WELLS R V / PRESENT ACTIVITY: MOVING RIG ONTO NE~ LOCATION ELEVAT. KB TO MSL DIST. KB TO BHF NLTA LTH/YTD LTA LTH/YTD DAYS SINCE LAST LTA LAST BOP TEST PROD. DEPTH 12170 PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 UATER DEPTH 80 116.0 DATE 38.4 DAY 4 / EST. DAY 4~ / DAYS +/- 855 LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED PP2 @ KILL SPEED SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 24.00 PUMPED LITE WATER INTO PIT #8. SET SLOPS TANK INTO WHR-2. RIG UP JACKS IN SUBBASE TO TURN RIG 180 DEG'S. REMOVED STARIS E/EAST SIDE OF CAMP AND SECURE DOORS. PULLED PUMP ~OIJSE_[~._PU~[E__D LITE WATER.~ANK. FILTER SKID AND ALL OTHER MISC EQUIP FROM AREA. PULLED WELDING SHOP BUILDING. T I M E ._(._H_R_S~_ CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOUg DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS REMOVED GU[DE BLOCKS FROM SUBBASE. TUR_.~N FE___.~E~ ON__JA__CKS. PUSHED RIG TO END OF SUBBASE. CUT OFF ESCAPE LADDER ON BACK OF RIG. R/u JACKS/POWER PACK ON MOON POOL. RIG UPPER STROM CLAMPS. TURNED RIG 90 DEGAS. WELD DOWN T~CK__S.~___~_F[N~SHED TURNING RIG 90 MORE DEGAS. REMOVED JACKS L/SUB. INSTALLED JACKS ON.~_~G___~LPU~L__~T/LEG 2. PULLED/PUSHED RIG T/~ 2~ CN~_ JACKS AND PUSHED EAST ~L__E~C~TER RAILS. GETTING ON LOCATION AT REPORT TIME. S$~=-~I ALASKA DAILY DRILLING REPORT .... PAGE 1 OF 1 gig NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: WELLS R V PROE. DEPTH 12170 PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 WATER DEPTH 80 / PRESENT ACTIVITY: WIRELINE WORK WHILE RIGGING UP ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY 5 NLTA LTH/YTD / EST. DAY 4~ LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 856 LAST BOP TEST LAST CSG TEST BHA INSPECTION ~CUM. ROT HRS) PP1 @ KILL SPEED @ PP2 @ KILL SPEED @ SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 24.00 CUT LOOSE AND REMOVE CENTER SKID BEAM. SET IN WELDING SHOP BUILDING. SET IN LITE WATER TANK~::[~:~R~ID AND TOOL LOCKERS ETC. SET IN MUD LINE. PUT UP AND .WELD IN CAT WALK TO IRON RACK. MAKE UP LITE WATER LINES. SET IN PUMP ROOM BUILDING. SET UP JACKS ON PONY SUB TO PULL RIG NORTH. RIG DOWN HELIPORT SERVICES. CLEAR EAST DECK. BUILD SCAFFOLDING AND- REMOVE EXUAST FAN F_./CAMP WALL TO ACCOMADATE RIG MOVE UP NEXT TO CAMP. CLEARED MUD PALLETS F/EAST MUD DOCK. SKID HELIPORT EAS!,=~IG=~P- SERVICE LINES. MOVED HOWCO PUMP AND HOUSE. SET STAIRS T/SUB. SKID RIG ABOVE PONY SUB NORTH. ~/U STORM CLAMPS. R/U_~AIR !/RIG. SKID RIG TOWARD CAMP. ~ON LOCAtiON) M/U LOWER STORM CLAMPS. RIGGING UP ELECTRICAL CABLES. SET IN BEAVER SLIDE. SET CAT WALK EXTENSION AND BOLT UP BEAVER SLIDE. SET DRLG LINE SPOOL ON DECK. PULL IN AC POWER CABLES AND WIRE IN. REPAIR HANDRAILS ON BEAVER SLIDE. R/_~_ SLICKLINE (TOM REESE1 PULL ~RONG~G F/LON~ ST~ING. WIRELINER CONTINUING AT RPT TIME TO PULL GAS LIFT VALVE FROM LONG STRING BETWEEN PACKERS. THEN WILL PULL SSSV FROM SHORT STRING AND RUN DUMMYfS IN BOTH STRINGS. ~NO SSSV IN LS[ .... ALL "AIT" MEMBERS: INVOICE FOR HS&E BONUS FOR A34-11LS...THE BONUS WE LOVE TO PAYlll GREAT JOB AND KUDO~S TO ALL!! LETS DO IT AGAINI*I*! T I M E (HRS2 ....... CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C&C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: CONTINUE RIGGING UP PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE 9~!!/9~ PRESENT DEPTH DIST. KB TO BHF 38.4 DAY FOOTAGE DRILLED NLTA LTH/YTD / EST. DAY 4~ SIZE OF LAST CSG 7.000 LTA LTH/YTD / DAYS +/- o DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA ~57 WATER DEPTH 80 LAST BOP TEST LAST CSG TEST ~8_/_.~.Z 9/_~_~. / BHA INSPECTION (CUH. ROT HRS) PP1 @ KILL SPEED @ PP2 @ KILL SPEED @ SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 24.00 WIRELINER UNABLE TO LATCH ONTO GAS LIFT VALVE BETWEEN THE PACK~=R/_.D_= SET UP HOWCO UNIT, H~USE AND P-TANK WHERE IT GOES.PULLED MORE ELECT. WIRE AND TERMINATE. UNSTACK PARTS/CHANGE HOUSES AND SPOT ON FINAL RESTING PLACES. RIG DOWN POWER PACK AND RIG JACKS AND STORE. PREP DECK FOR BOAT LOAD OF EQUIPMENT COMMING OUT. CUT LOOSE AND REMOVE WEST SIDE SKID RAIL. SWAP BUFFALO FAN AND LOUVERS IN PUMP ROOM. INSTALLED 2" WATER LINE TO RIG. RE-ROUTE AND CONNECT REMOTE KOOMY CONTROL CABLE. ROUTE AND PLUMB IN KATO GEN FUEL LINE. INSTALL LID ON SLOP TANK. WELD DOWN MUD LINE CLAMPS/SUPPORTS, FAB/INSTALL DUCT BOXES AND 10" HOSE FOR CAMP EXUAST FAN. TIE UP WIRES ONSIDE OF RIG. MOVE SOUTH SIDE PiPE RACK REMOVE BEAVER SLIDE AND HANG FLOWLINE HEADER. INSTALL WALKWAY TO PARTS HOUSE FROM KATO ROOF. TIE IN ELECTRICAL LINES IN PUMP ROOM. NOTE: HAD 2 TO ] GAL DIESEL SPILL TO THE WATER. ALL AUTHORITIES WERE NOTIFIED AND PAPER WORK TRANSMITTED. MEASURES HAVE BEEN TAKEN TO PREVENT RECURRENCE OF LIKE INCIDENT. TIME CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C&C REAMING SURVEYS JET REPAIRS FISHING NiP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "~" WELL A41A-11 UORK ORDER 739930 SIDE TRACK £PI ALASKA DAILY DRILLING REPORT PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 PRESENT DEPTH DIST. KB TO BHF 38.4 FOOTAGE DRILLED NLTA LTH/YTD / SIZE OF LAST CSG 7.000 LTA LTH/YTD / DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 858 PAGE 1 OF 1 DATE ~8.~!~/9[ DAY EST. DAY 45 DAYS WATER DEPTH DRILLING FOREMAN: WELLS R V / PRESENT ACTIVITY: CONTINUE WITH RIG UP 80 LAST BOP TEST BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED PP2 @ KILL SPEED SUMMARY OF OPERATIONS (SHO~ HOURS FOR EACH OPERATION) : 24.00 HANG 10" FLO~ LINE TO HEADER MANIFOLD. FAB AND INSTALLING 6" CHOKE AND WATER RETURN LINES. HANG ESCAPE LADDER ON WEST SIDE OF DOG HOUSE. RESET BEAVER SLIDE. PREP TO LEVEL DERRICK; LOOSEN CLAMPS ON STAND PIPE AND CEMENTING STAND PIPE. DISCONNECT VENT LINE ON GAS BUSTER AND STEAM LINES. LOOSEN DERRICK LEG BOLTS. REMOVE SHIMS FROM WEST SIDE OF DERRICK AND INSTALL ON THE EAST SIDE. SHIM_gUT HEATEES,..~.GAS BUSTER.___ RECLAMP STA~D PIPES, GREASE AND TIGHTEN DERRICK LEG BOLTS. INSTALL 6" AUGER IN PITS HALLWAY. (AUGER HAS BEEN TOTALY REBUILT) POUER CHECK D~KS. PU~PS, ROTARY TABLE, TOP DRIVE, AIR SYSTEMS. "A" CIRCUT~A~LE~,_ TROUBLE SHOOTING FOUND A BAD CONNECTION IN CONTROL CABLE WIRES. TOP DRIVE CONTACTOR COIL IS FRIED. MUST FIND REPLACEMENT. REBUILT TRASH PUMPS. CHECK OUT SUCTION VALVES AND RISERS IN PITS. FAB 6" EXTENSION LAST CSG TEST FROM RIG TO PIPE RACK. WELD AND HANG 4" CHOKE LINE. LEVEL CATWALK. BEGIN PLUMING IN SLOPS TANK FROM WHR-2 TO PITS. REPAIRED UA" CIRCUT CONTROL CABLE END CONNECTOR. T I M E .~_HR_S CUM. ROT. HMS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DOIJN DS INSPECT BHA RIG UP/TEAR DOWN UAIT ON WEATHER/MAT EVALUATION CORING OTHERS 24.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM NAa UELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: WELLS R V / PRESENT ACTIVITY: FINISHING RIG UP ELEVAT. KB TO MSL DIST. KB TO BHF NLTA LTH/YTD LTA LTH/YTD DAYS SINCE LAST LTA LAST BOP TEST PROG. DEPTH 12170 PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 WATER DEPTH 80 116.0 DATE ~8/!~/~! 38.4 DAY 8 / EST. DAY 45 / DAYS +/- 859 LAST CSG TEST 9~L~Z~! BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED PP2 @ KILL SPEED CUM. ROT. HRS ROTATING HUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/IJH TESTING BOP /IJH RUNNING CASING CEMENTING PICKUP/LAY DOUN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS SUMMARY OF OPERATIONS (SHO~ HOURS FOR EACH OPERATION) : 24.00 OR~RE_._.~D~ RECEIVED AND INSTALLED TOPDRIVE RELAY FOR CONTROL CIRCUT. IT HELPED TO THE EXTENT THAT IT IDENTIFIED A PROBLEM ~ITH THE "PLC" AND OR PROM CARD. WE WILL CONTACT "TECH PO~ER" CONTROLS COMe,NY [ODA~L___- BUILDERS OF THE SYSTEM FOR HELP/PARTS AS NEEDED. PULLED CONTROL CABLE FOR SLOPS TANK TO NCC PANEL FROM WHR-2. FINISHED PLUMBING IN SLOPS TANK. WATER SYSTEM CHARGED AND LEAK TESTED. PUT KATO GEM SET ONLINE. FINISHED EXTENSION ON 6" AUGER SYSTEM. SILICONE HATCH COVERS. CLEAN PITS~ DISPOSE OF FLUIDS. FILL PITS WITH RAW SEAWATER. ~PITS 3 &_4) SQUARING RIG AWAY FOR OPERATIONS. SPOT SCHLUMBERGER UNIT ON CATWALK. 24.00 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM ~ELL A41A-11 WORK ORDER 739930 ~.-~-.SWEPI ALASKA DAILY DRILLING REPORT ,~OG. DEPTH 12170 ELEVAT. KB TO MSL PRESENT DEPTH 7765 DIST. KB TO 8HF 38.4 FOOTAGE DRILLED NLTA LTH/YTD / SIZE OF LAST CSG 7.000 LTA LTH/YTD / DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 860 116.0 PAGE 1 OF 1 DATE ~L!EL~ DAY 9 EST. DAY 45 DAYS +/- SIDE TRACK WATER DEPTH DRILLING FOREMAN: WELLS R V / PRESENT ACTIVITY: LOADING WELL ~/8=5:PPG SEAWATER 8O LAST BOP TEST LAST CSG TEST ~8_.~/9~ BHA INSPECTION (CUM. ROT HMS) PP1 @ KILL SPEED @ PP2 @ KILL SPEED @ SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 3.50 FINISHED RIGGING UP. PROD SAFETY AIR UORKING ON RIG FLOOR. 5.00 ~/U SUS. HELD S~[ETY/PROCEDURES MEETING. M/U TBG PUNCH U/7 SHOTS. NIH ~/PU~CH [LON~_ST[IN~ AND SHOOT HOLES AT 6394', TBG_~I: DROPPED 200#. POH.c_RI.RI~_DOW~ SUS. 3.00 MONITOR LONG STRING.._~PRESSUR~_U~T~5~_TO 430 PSI IN .5 HRS. REPAIR HATCH COVER THAT ~AS CUT UP ON PREVIOUS ~ELL ~ORK. RIG UP SLICKLINE. 9.50 TEST LUBRICATOR. RIH ~/KICKOVER TOOL T/PULL #5 VALVE FROM LONG STRING AT 5992~. NO SUCESS._~H6NGE-T~L TYPE~ RIH. L~TC~ ONTO VALV_..~_c_EPOH. RI'H AND SET "XEL~ OUMMY AT 283~. POH. R/D_F~OM LONG:STRING._RIG UP ON SHORT STRING. TEST LUBRICATOR. RIM AND RETRIEVE BALL VALVE FROM 318~. ~/U CHOKE RETRIEVING TO0~. RIH A~D RETRIEVE OTIS CHOKE REGULATOR FROM 6049~. M[U. RIH AND SET #XEL" DUMMY VALVE AT 318~. ~/D SLICKLINE. 1.0~ REMOVE FISHER REGULATOR VALVE ASSMY FROM SHORT STRI~ SIDE.:INSTALLED HARD LINE.F/~HORT STRING TO PROD HEADER. BLED OFF ANULUS T_/PROD HEADER 2.00 PUMP 8.5 SEAWATER DOWN LONG STRING TAKING RETURNS OUT SHORT STRING UNTIL HAD CLEAN RETURNS. PUMP 8.5 SEAWATER DOWN LONG STRING UNTIL HAD CLEAN RETURNS OUT ANULUS. TIME__~R...~S2 CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C 2.00 REAMING SURVEYS JET REPAIRS 3.00 FISHING NIP UP/DO~N /BOP/WH TESTING BOP /~H RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOgN 3.50 WAIT ON ~EATHER/MAT EVALUATION CORING OTHERS 15.50 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREM~N: WELLS R V PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE ~8_L!~9~ PRESENT DEPTH 7765 DIST. KB TO BHF 38.4 DAY 10 FOOTAGE DRILLED NLTA LTH/YTD / EST. DAY ._~4~ SIZE OF LAST CSG 7.000 LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 861 WATER DEPTH 80 LAST BOP TEST 98_/_.~/_~ LAST CSG TEST ~8_L~/9~ / BHA INSPECTION (CUM. ROT HRS) PRESENT ACTIVITY: PULLING ON PACKER .~.~LD__UAL STRINGS SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 6.00 SHUT IN ~ELL AND MONITORLRECORD BOTH TBG PRESSURES AND ANULUS PRESSURE UHILE MIXING KILL UEIGHT FLUID USING STOCK SALT TO 9.4 PPG. KILL WELL. PP1 @ KILL SPEED PP2 @ KILL SPEED ClRC DOWN LONG STRING TAKING RETURNS OUT ANULUS UNTIL NAD 9.4 PPG. PUMP DOWN LONG STRING TAKING RETURNS OUT SHORT STRING UNTIL NAD 9.4#. CHECK f/[L~. NONE. 13.50 INSTALLED BPV IN EACH STRING. N.._~.L~TREE.~N/U BOPE.- 4.00 TEST BOPE~ RAMS ONLY. ~ILL TEST BLINDS AND ANULAR PREVENTOR WHEN OUT OF THE HOLE WITH THE DUAL STRING. .5~ BACK OUT LOCK DOWN SCREWS ON TBG HANGERS. PULLING ON PACKER AT RPT TIME. I TIME.~R_.~S2 ....... I CUM. ROT. HRS J ROTATING I MUD MOTOR J TRIPPING Ic&c 6.00 J REAMING J SURVEYS J JET J REPAIRS J FISHING J NIP UP/DOWN /BOP/UH 13.50 J TESTING BOP /WH 4.00 J RUNNING CASING J CEMENTING J PICKUP/LAY DOWN DS J INSPECT BHA J RIG UP/TEAR DOWN J WAIT ON WEATHER/MAT J EVALUATION J CORING J OTHERS .50 ! ALASKA DAILY DRILLING REPORT PAGE I OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: LAYING DOWN TBG PROG. DEPTH 12170 PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 WATER DEPTH 80 / ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY 1 NLTA LTH/YTD ___/___ EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 862 LAST BOP TEST ~8/1~/9~ LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PPl@ KILL SPEED @ PP2 @ KILL SPEED @ SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.00 PULL PKR LOOSE WITH 17~,000 (PKR. DRAGGING) 1.00 [/U TO CIRC. WE~:~NOT~z TBG WAS NOT LINED UP I~ BOPS, MASHED LANDING JT. ON LONG STRING WHEN BOPS CLOSED) 4.00 CIRC. LONG AND SHORT STRINGS 4.00 HOLD PRE-JOB SAFETY MEETING (HAZARDS LAYING DOWN DUAL STRING) - PULL PKR UP HOLE 38m(DRAGGING 150,000) - PKR STUCK - CONSULT WITH HOUSTON ENGINEERING TO DETERMINE MAX. PULL ON DUAL STRING WITH MASHED JT. - ~L=20~.OOO_TO GET TBG HANGER ABOVE SLIP AREA - SET SLIPS - L/~ MASH- ED JT AND PULL BOTH BPV'S - PULL 205~O00_A. ND=~KR CAME FREE .(.~RAGGINGZ_ 14.00 ~/D TBG. & MISC. TOOLS MAX. BOTTOMS UP GAS - 42% LEL NOTE~ DIALOG WIRELINE OPERATOR ON LOCATION IN CASE PKR STICKS. TIME ,~URSI ..... CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C&C 4.00 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH .... TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 14.00 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 6.00 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM WELL A41A-11 WORK ORDER 739930 SWEPI ALASKA DAILY DRILLING REPORT · PROG. DEPTH 12170 ELEVAT. KB TO M'~L 116.0 PRESENT DEPTH 7279 DIST. KB TO BHF 38.4 FOOTAGE DRILLED NLTA LTH/YTD / SIZE OF LAST CSG 7.000 LTA LTH/YTD / DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 863 PAGE 1 OF 1 DATE gB_~!Z/9~ DAY 12 EST. DAY 45 DAYS +/- SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: ~/U BHA WATER DEPTH 80 / SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 7.00 L/D 2 3/~# TBG & MISC. TOOLS - NOTEj FOUND HOLE IN COLLAR ON SHORT STRING. BOTTOM JT. ON SHORT STRING WAS LOOSE IN PKR. (HAND TIGHT~ .... 1.00 ORGANIZE RIG FLOOR - CHANGE RAMS TO 3.5~ LAST BOP TEST 9~!~/9~ LAST CSG TEST ~Z/9~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 30 @ 475 PP2 @ KILL SPEED 50 @ 900 2.00 TEST RAMS (PIPE & BLIND) ~0 2~0/5000 PSi - TEST HYDRIL TO 250/3500 PSI PULL TEST PLUG~INSTALL WEAR BUSHING. 1.00 ~/U BHA (PKR. MILLING ASSEMBLY~ 3.00 TIN TO 6409~ .50 MILL ON PKR. @ 6436~ 1.00 SHUT WELL IN & CIRC. OUT GAS (59~ L[[) = 3.00 MILL ON PKR. TO 6438~ - PKR. WENT DOWN HOLE .50 PUSH PKR TO 7279' 1.00 CIRC. BOTTOMS UP 1.00 REVERSE CIRC. ON TOP oF PKR. (TWO VOLUMES - DID NOT GET ALOT OF DEBRI~ FROM REVERSING~ 2.00 POOH 1.00 ~/D_MILL & BOOT BSKTS. - P/U SPEAR NOTEi__[/D_~I_2 JT 3.5" DRILL P]PE_~/ WASHED PIN END. ALL JUNK BSKTS HAD METAL INSIDE - GOOD RECOVERY __GREAT JOB DONE BY ALASKA CASING & INLET DRILLIN~~ LAYING DOWN DUAL STRING! NO INJURIES - NOTHING BROKE TIME (HR~_.~_ CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING 5.50 C&C _3.00 REAMING SURVEYS JET REPAIRS FISHING 3.50 NIP UP/DOWN /BOP/WH TESTING BOP /WH 2.00 RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 9.00 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 1.00 dEPI ALASKA DAILY DRILLING REPORT PAGE I OF 1 RIG NAME PLATFORM "A# FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "Aa UELL A41A-11 UORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: M/U BHA PROG. DEPTH 12170 PRESENT DEPTH 7721 FOOTAGE DRILLED SIZE OF LAST CSG 7'.000 DEP. OF LAST CSG 7765 UATER DEPTH 80 / ELEVAT. KB TO MSL 116.0 DATE g8118/_~ DIST. KB TO BHF 38.4 DAY 13 NLTA LTH/YTD / EST. DAY 45 LTA LTH/YTD ~/___ DAYS +/- DAYS SINCE LAST LTA 864 LAST BOP TEST ~8/16/9~ LAST CSG TEST O__~Z/9~ BHA INSPECTION (CUM. ROT HRS) PP1 a KILL SPEED 30 @ 300 PP2 @ KILL SPEED 50 8 575 L · SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : .50 BHA - M/U SPEAR ASSEMBLY 2.00 TIH TO 7268' 1.50 CIRC BOTTOMS UP (LOU RATE THROUGH SMALL I.D.) .50 SPEAR FISH 4.00 TOOH (SLOU - DRAGGING) 1.00 ~/D FISH - BAKER DB PKR, SEAL:BORE_~XT, XO, XO, (1) JT 2 3/8~ TBG, OTIS "X" NIPPLE, (1) JT 2 3/5" TBG,.MECP. TBG RELEASE, 2 3/8" TBG SUB= 89.20~ 1.00 BHA - M/U 5 7/8" OVERSHOT 3.00 TIH TO 7345~ .50 CIRC BOTTOMS UP (MAX GAS AT PITCHER NIPPLE - 80~ LEL~ 1.00 UORK OVER GUNS ~ 7'564' - JAR ON FISH 3.50 TOOH U/FISH 1.00 BHA__- L/D JAR~, BS, & O/S 4.00 HOLD PRE-JOB SAFETY MEETING - LID SPENT GUNS NOTE; GUNS HAD TRAPPED PRESSURE - SLOU BLEEDING PRESSURE & LAYING DOUN. HALLIBURTON SUPERVISOR RELEASED PRESSURE & ASSISTED IN LAYING DOUR GUNS. .50 ~A - M/U,,6# BIT, JUNK, BSKTS~ & JARS NOTE; CLEANING PITS & PREPARING MIN. OIL MUD UHILE TRIPPING. FISH #2 - PORTED PRESSURE EQ._SUB,. (1) JT 2 3/8~ TBG. FIREING HEAD EXT, FIRING HEAD, 307' GUNS, STEEL BALL PLUG = 374' TIME (~RS) . CUM. ROT. HRS ROTAT I NG MUD MOTOR i TRIPPING T2-~ I c&c ;,.oo J REAMING SURVEYS JET REPAIRS FISHING 1.50 NIP UP/DOUR /BOP/UH TESTING BOP /UH .. RUNNING CASING CEMENTING PICKUP/LAY OOUN DS 8.00 INSPECT BHA RIG UP/TEAR DOuR UAIT ON UEATHER/MAT ~ EVALUATION CORING OTHERS ...... SUEPI ALASKA DAILY DRILLING REPORT PAGE I OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" UELL A41A-11 UORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: MOTOR DRILLING PROG. DEPTH PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 UATER DEPTH 80 ./ SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : 1.00 pH~A - M/U RR BIT ~1~_(5~ JUNK 8S~T~S, UP JAR~. (6) DC~.S, & PO SUB .50 DRAIN STACK & STAB BIT THROUGH UEAR BUSHING (6" HOLE THROUGH 13 5/8~ RISER. 3~~ AUAY) 3.00 TIH - FILL PIPE g 4980' & 7644' .50 TAG FILL g 7687' - DRILL TO 7721' 4.00 DRILL FLOAT, CMT. & SHOE .50 FLUSH STAND PIPE & MUD LINE U~MIN. OIL MUD 1.00 DRLG. FROM 7765~ TO 7774' 12170 ELEVAT. KB TO MSL 116.0 DATE 7805 DIST. KB TO 'HF 38.4 DAY 14 40 NLTA LTH/YTD '____/_ EST. DAY LTA LTH/YTD __/_ DAYS +/- +4.0 DAYS SINCE LAST LTA 865 LAST BOP TEST ~8/16/95 LAST CSG TEST BHA INSPECTION (CUM. ROT HAS) PP1 a KILL SPEED 30 PP2 g KILL SPEED 5.___~0 g _ : 1.00 LEAK OFF TEST - PERFS TAKING FLUID - APPROX. 10.5 PPG EQUIV. 1.50 CIRC. & CONDITION MUD - MIX DRY JOB - FILL TRIP TANK 2.00 TOOH FOR MOTOR 3.00 BHA - L/D BIT &* JUNK BSKTS - ~[~ MOTOR ASSEMBLY 2.50 TIH - FILL PIPE & CHECK MUD @ 4547' .50 REAM SHOE & UORK BOTTOM FOR JUNK 3.00 ROTARY, OR[ENT~.& MOTOR DRLG FROM 7774' TO 7805' NOTE;. REC. APPROX. 4 GAL OF METAL DEBRIS FROM JUNK BSKTS. TIME (HRS) CUM. ROT. HRS 8.00 ROTATING 6.00 MUD MOTOR 2.00 TRIPPING 7.50 c & C 1.50 REAMING 1.00 SURVEYS JET REPAIRS FISHING NIP UP/DOUR /BOP/UH TESTING BOP /UX RUNNING CASING CEMENTING PICKUP/LAY DOUR DS 4.00 INSPECT BHA RIG UP/TEAR OOUN ~ UAIT ON UEATXER/MAT ~ EVALUATION _~ CORING OTHERS 2.00 RIG NAME PLATFORM aA" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM UELL A41A-11 UORK ORDER 739930 ~IEPI ALASKA DAILY DRILLING REPORT PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 PRESENT DEPTH 8087 DIST. KB TO BHF 38.4 FOOTAGE DRILLED 282 NLTA LTH/YTD ____/____ SiZE OF LAST CSG 7.000 LTA LTH/YTD ___/ DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 866 PAGE 1 OF I DATE 08/20/95 DAY 15 EST. DAY 45 DAYS +/- SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: MOTOR DRLG. UATER DEPTH SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH, OPERATION) : 24.00 ROTARY/ORIENT/MOTOR DRILL FROM 7805t TO 8087~ NOTE; TOTAL CIRC./DRILL HRS. ON BiT #2 = 27.5 80 LAST BOP TEST ~8/'~/9~ LAST CSG TEST ~8_/_~7_./__~.~ BHA iNSPECTiON (CUM. ROT HRS) PP1 @ KiLL SPEED 30 @ 110 PPZ @ KILL SPEED 50 @ 160 TIME CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C&C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOUN /BOP/UH TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DOUR DS INSPECT BHA RIG UP/TEAR DOUR UAIT ON UEATHER/MAT EVALUATION CORING OTHERS 29.50 11.50 10.00 1.00 1.50 RIG NAME PLATFORM NAil FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" UELL A41A-11 UORK ORDER 739930 SIDE TRACK SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE ~8/~!/,~ PRESENT DEPTH 8271 DIST. KB TO BHF 38.4 DAY 16 FOOTAGE DRILLED 184 NLTA LTH/YTD / EST. DAY 45 SIZE OF LAST CSG 7.000 LTA LTH/YTD ___/___ DAYS DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 867 UATER DEPTH 80 LAST BOP TEST ~8.8.~!~/9~ LAST CSG TEST DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: SLIPPING DRLG. LINE SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : 15.00 ROTARY/ORIENT/MOTOR DRLG. FROM 8087t TO 8272' .50 CHECK FLOU - PULL TO SHOE (SLIGHT OVERPULL - DRAGGING COALS~ 4.00 PUMP PILL - DROP DART/SHEAR P/O SUB - TOOH BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED 975 @ 30 PP2 @ KILL SPEED 1500 @ 50 2.00 BHA - ~[~ MOTOR & STABS - STAND BACK MORELS - M/U STEEL ROTARY ASSEMBY 2.50 TIH - FI-LL PIPE @ 5000~ & SHOE TOTAL CI~C./DRILL HRS. BIT #2 = 42 IADC DULL GRADE BIT #2 - 3-3-ER-A-E-I-UT-HRS NOTEZ ANADRILL DAY/COST CURVE INFO. NOT UPDATED - JEFF TO GET THEM UPDATED ~A~Y~COST NUMBERS TODAY (UE ARE DOING BETTER THAN' IT APPEARS). T i H E_~it RS.Z .... CUM. ROT. HRS 42.75 ROTATING 7.75 MUD MOTOR 5.50 TRIPPING 7.00 C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOUR /BOP/UH TESTING BOP /UH RUNNING CASING CEMENTING PICKUP/LAY DOIJN DS INSPECT BHA RIG UP/TEAR DOUR UAIT ON UEATHER/MAT EVALUATION CORING OTHERS .75 1.00 2.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIELD HIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: ROTARY DRLG. PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE PRESENT DEPTH 8547 DIST. KB TO BHF 38.4 DAY 17 FOOTAGE DRILLED 276 NLTA LTH/YTD / EST. DAY 45 SIZE OF LAST CSG 7.000 LTA LTH/YTD __/___ DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA ~6._~8 WATER DEPTH 80 LAST BOP TEST 98/1_~6/9~ LAST CSG TEST / BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 72~ @ 30 PP2 a KILL SPEED 1400 @ 50 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.00 CUT & SLIP DRLG. LINE .50 TIH - TAG a 8140t .50 REAM TO BOTTOM 22.00 ROTARY DRILL FROM 8271' TO 8547' 64.75 NOTE; AT 8289t P/~ OFF BOTTOM TO WIPE HOLE - KICKED OUT TOP DRIV._.~E~__ DUE TO TORQUE - GOT STUCK - JARS WENT OFF TWICE GOING UP : :: (UNINTENTIONAL) - JARED DOWN TWICE - CAME FREE - NO MORE PROBLEMS AFTER. NOTE L.__~/U & WIPE HOLE EVERY 1-2 HRS. NOTE; NEXT BIT RUN WILL PLU HIGH SPEED MOTOR (ATTEMPT TO INCREASE P RATE) T 114 E (HRS.)_ ...... CUM. ROT. HRS ROTATING 22.00 MUD MOTOR TRIPPING .50 C & C REAM I NG .50 SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/UH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS I .00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WEll A41A-11 WORK ORDER 739930 SIDE TRACK ORILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: TRIPPING PROG. DEPTH 12170 PRESENT DEPTH 8721 FOOTAGE DRILLED 174 SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 WATER DEPTH 80 /GALLOWAY DR SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 16.50 ROTARY DRLG. FROM 854~' TO 8721' 3.50 CHECK FLOW - TOOH (NO BAD SPOTS IN OPEN HOLE2 3.50 P_/_~IO_.~SJTS_~3~!Z~" DP .50 CIRC. THROUGH DP [PRIOR TO RUNNING MWD~ ELEVAT. KB TO MSL 116.0 DATE ~8/2~3/9~ DIST. KB TO BHF 38.4 DAY 18 NLTA LTH/YTD / EST. DAY ._~4~ LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 869 LAST BOP TEST ~8/1~/9~ LAST CSG TEST 08_.~/9~ BHA INSPECTION (CUM. ROT HRS) PP1 g KILL SPEED 610 @ 30 PP2 @ KILL SPEED 950 @ __52 T I ME .~UR~S,)____~_ CUM. ROT. HRS 81.25 ROTATING 16.50 MUD MOTOR TRIPPING 3.50 c & c _ .5___~o REAMING SURVEYS JET _~ REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS _3.50 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT __ _ EVALUATION __~ CORING .... OTHERS SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PROG. DEPTH 12170 PRESENT DEPTH 8805 FOOTAGE DRILLED 84 SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 WATER DEPTH 80 __B/GALLOWAY DR PRESEHT ACTIVITY: PULLING MWD ~L~IALOG ELEVAT. KB TO MSL 116.0 DATE ~8__~/_~ DIST. KB TO BHF 38.4 DAY 19 NLTA LTH/YTD ___/___ EST. DAY 45 ___ LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 870 LAST BOP TEST ~L~L~ LAST CSG TEST ~8/~Z/9~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 420 @ 30 PP2 @ KILL SPEED 1460 @ 50 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : .50 CIRC. THROUGH PIPE - PUMP DRY JOB 1.00 TOOH 2.00 BHA - L/D STEEL ASSEMBLY - P_.~UHIGH_~SPE[~M~!O__~R~_M__~.~._~&_MONELS 3.50 TIH - FILL PIPE @ 4920' & SHOE 1.00 REAM FROM 8008~ TO 8023~ - GOT STUCK - WORK FREE - REAM TIGHT SPOT @ 8320' - SURVEY @ 8345' & 8637' 6.50 DRLG. WfMOTOR FROM 8721' TO 8805' NOTE~ ROTATE UP OFF BOTTOM TO CHANGE MUD PUMPS - GOT STUCK 3' OFF BOTTOM. 9.50 JAR DOWN & UP ON STUCK PIPE - MIX & PUMP WEIGHTED HIGH VIS PILL - MOBILIZE DIALOG & WEATHERFORD -RIH ~/DZ~LO~_TO_EET~EVE_MWD - DIALOG LOST CIRCUT ON BOTTOM (NO COLLAR LOCATOR~ - TIGHT SPOT @ 8616' - PULL OUT OF HOLE_.~NO TOOL.)__- NIH - WORK THROUGH TIGHT SPOT @ 8621' - LATCH ON TOOL - PULL OUT OF HOLE ~ADDITIONAL 400 LBS~ IADC DULL BIT GRADING BIT #3 - 3-3-CT-G-E-1~16-ER-HRS TIME ,~[~2_ CUM. ROT. HRS 87.75 ROTATING 6.50 MUD MOTOR TRIPPING 4.50 C & C .50 REAMING 1.00 SURVEYS JET REPAIRS FISHING 9.50 NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA 2.00 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE ~L~/_~ PRESENT DEPTH 8808 DIST. KB TO BHF 38.4 DAY 20 FOOTAGE DRILLED NLTA LTH/YTD / EST. DAY 45 SIZE OF LAST C~G 7.000 LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST ETA 871 WATER DEPTH 80 LAST BOP TEST ~8/~E/9~ LAST CSG TEST ~8/07/9~ ...... /GALLOWAY DR BHA INSPECTION (CUM. ROT HRS) PRESENT ACTIVITY: REAMING OPEN HOLE TO BOTTOM SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : .50 Bp~t (DIA-L~) , 2.50 JAR ON STUCK PIPE - MAX PULL 390K. PP1 @ KILL SPEED 420 @ 30 PP2 @ KILL SPEED 1460 @ 50 1.50 PUMP HIGH VISC.__(11.8#) SWEEP - 50 BBLS. INSPECTED DERRICK FOR LOOSE OBJECTS DURING SWEEP. 2.50 REDUCED PUMP SPM WITH SWEEP AT BIT AND CONTINUED JARRING OPERATIONS. JARRING DOWN WITH 75K - JARRING UP WITH 325K AND MAX PULL 390K. IMPLEMENTATION AND TECH AIT TEAM CONFERENCED TO DISCUSS SITUATION AND OPTIONS. DECISION WAS MUTUALLY M6DE__TO[EEE_ROIN._~.T~HOO___~._TOF[x AND SET CEMENT PLUG TO SIDETRACK. WHILE TEAM WAS MEETING FISH CAME FREE. POH WITH BHA TO SHOE. TIGHT SPOTS IN OPEN HOLE FROM 8808 TO 8060' 2.00 DROPPED BAR AND SHEARED PUMP OUT SUB. CIRC OUT HIGH VIS PILL. 2.00 POH WITH BHA. 1.00 ~/D ENTIRE BHA FOR INSPECTION. 4.50 CONTACTED AOGCC WHO DECLINED WITNESS OF BOP TEST. PERFORMED SUCCESSFULL UEEKLY BOP TEST. 1.50 ~/U BIT #5 AND BHA. IACD BIT GRADE BIT #4 4-4-CT-N-E-I-ER-HP 2.50 RIH WITH BHA. 'FILL PIPE AT 4950~ AND CSG SHOE. 1.50 CUT AND SLIP 100' OF DRILL LINE. SERVICE TOP DRIVE. 2.00 CONT TO RIM AND TAGGED UP AT 8323~. BROKE CIRCULATION AND WASHEDZ ..... REAMED FOR 8323~ TO 8798'. REAMING TO BOTTOM AT REPORT TIME. NOTE: THANKS TO ALL AIT TEAM MEMBERS FOR THIER TIME AND ASSISTANCE WITH THE RECENT HOLE PROBLEMS. TIME CUM. ROT. HRS 87.75 ROTATING MUD MOTOR TRIPPING 4.50 C & C 3.50 REAMING 2.00 SURVEYS JET REPAIRS 1.50 FISHING 5.00 NiP UP/DOWN /BOP/WH TESTING BOP /UH 4.50 RUNNING CASING CEMENTING PICKUP/LAY DOWN DS ]NSPECT BHA 2.50 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS .50 SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM UA" ~ELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: TRIPPING PROG. DEPTH 12170 PRESENT DEPTH 8993 FOOTAGE DRILLED 185 SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 UATER DEPTH 80 /GALLOWAY DR SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.00 REAM TO BOTTOM 18.00 ROTARY DRILL FROM 8808' TO 8993' 1.00 CHECK FLOW AND PUMP DRY JOB. 3.00 POH WITH BHA. ELEVAT. KB TO MSL 116.0 DATE ~8/~/9~ DIST. KB TO BHF 38.4 DAY 21 NLTA LTH/YTD / EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST ETA 872 LAST BOP TEST ~8_.~E/~~ LAST CSG TEST BHA INSPECTION (CUM. ROT HAS) PP1 @ KILL SPEED 700 @ 20 PP2 @ KILL SPEED 1050 @ 40 1.00 L/D BHA AND BEGAN PICKING UP BHA WITH BIT #6. PICKING UP BHA AT REPORT TIME. NOTE; RAISED MUD UT. TO 9.9 PPG IN HOPES TO PREVENT UPPER HOLE FROM SLOUGHING. IADC DULL BIT GRADE BIT #5 - 8-8-CR-N-F-16/!6-BC/BT/R0 ........... NOTE: TUBOSCOPE REP. ON PLATFORM TO INSPECT BHA AFTER JARRING OPERATIONS. INSPECTION FOUND (3) BAD BOXES AND I BAD PIN AS A RESULT OF GALLED DAMAGE. TIME ~URSZ ....... CUM. ROT. HAS 105.75 ROTATING 18.00 MUD MOTOR TRIPPING 3.00 C & C 1.00 REAMING 1.00 SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA 1.00 RIG UP/TEAR DO~N WAIT ON WEATHER/MAT EVALUATION CORING OTHERS SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" UELL A41A-11 ~ORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: ROTARY DRILLING PROG. bEPTH 12170 PRESENT DEPTH 9148 FOOTAGE DRILLED 155 SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 WATER OEPTfl 80 /GALLOWAY DR SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.00 CONT. TO PICK UP 3.5" HUDP TO COMPLETE BflA. 2.50 RIH WITH BHA. FILL DRILL PIPE AT 5000' AND SHOE. ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY 22 NLTA LTfl/YTD / EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 873 LAST BOP TEST ~8_/__~./9~ LAST CSG TEST 08__~_~/9~ BHA INSPECTION (CUM. ROT HAS) PP1 @ KILL SPEED 86~0 PP2 @ KILL SPEED 1340 @ 40 2.00 WASHED/REAMED FROM 8700' TO 8993'. FANNED BOTTOM TO CLEAN UP ANY DEBRIS LEFT FROM BIT #5. 17.50 ROTARY DRILL FROM 8993' TO 9148'. T I M E .(.fiRS)_, CUM. ROT. HAS ROTATING MUD MOTOR TRIPPING 2.50 Ic&c REAMING 2.00 SURVEYS I JET I REPAIRS FISHING NiP UP/DOWN /BOP/WH TESTING BOP /UH RUNNING CASING CEMENTING PICKUP/LAY DOUR DS 2.00 INSPECT BHA RIG UP/TEAR DOUR WAIT ON UEATHER/MAT EVALUATION CORING OTHERS 123.25 17.50 ~wEPI ALASKA DAILY DRILLING REPORT RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM WELL A41A-11 WORK ORDER ?39930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: ROTARY DRILLING PROG. DEPTH 12170 PRESENT DEPTH 9283 FOOTAGE DRILLED 135 SIZE OF LAST CSG 7'000 DEP. OF LAST CSG 7765 WATER DEPTH 80 /GRLLOUAY D~ SUMMARY OF OPERATIONS (SNOW HOURS FOR EACH OPERATION) : 1.50 ROTARY DRLG. FROM 9148t TO 9156t 1.00 CIRC. &.SURVEY (ANGLE ONLY) 4.00 TOOH (GOOD TRIP THROUGH OPEN HOLE) 1.50 BHA - L~D STEELS - P/U MOTOR & MUD 3.00 TIH Y/MOTOR - FILL PIPE @ 4400' & SHOE PAGE I OF 1 ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY 23 NLTA LTH/YTD / EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 874 LAST BOP TEST ~8/~E/9~ LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 1200 @ 20 PP2 @ KILL SPEED 1780 @ 40 .50 REAM TO BOTTOM FROM 9076' - ATTemPT TO SURV~Y_~_~N~_.~GOO_~.~_~D _~D TO THICK 1.00 DRLG. Y/MOTOR FROM 9156~ TO 9171~ .50 MUD PUMP PROBLEMS 11.00 DRLG. Y/MOTOR FROM 9171' TO 9283~ IADC DULL GRADE B~T #6 - 7-8-BT-A,~&H-~-4-~G&E._.~R-I'~ NOTE~ RUNNING MUD MOTOR IN ATTEMPT TO INCREASE P RATE - DID NOT MAKE ANY DIRECTIONAL CORRECTIONS. CUM. ROT. HRS 136.75 ROTATING 13.50 MUD MOTOR TRIPPING 7.00 C & C 1.00 REAMING .50 SURVEYS JET REPAIRS .50 FISHING NIP UP/DOUN /BOP/WH TESTING BOP /~H RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BNA 1.50 RIG UP/TEAR WAIT ON gEATHER/MAT EVALUATION CORING OTHERS RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM aA" WELL A41A-11 WORK ORDER 739930 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE PRESENT DEPTH 9415 DIST. KB TO BHF 38.4 DAY 24 FOOTAGE DRILLED 132 NLTA LTH/YTD / EST. DAY 45 SIZE OF LAST CSG 7.000 LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 875 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: DRILLING WATER DEPTH /GALLOWAY DR 8O SUMMARY OF OPERATIONS (SHOg HOURS FOR EACH OPERATION) : 8.50 ROTARY DRILL g/1 1/4 DEG MOTOR FROM 9283' TO 93?0'. 1.00 CHECK FLOg AND PUMP DRY JOB. 3.50 POH gITH BHA AND BIT #7. .50 L/~=BHAj...,.M._.~U~, AND FLEX COLLAR'S. 1.00 ~/U STEEL ROTATING BHA WITH BIT #8. 3.00 RIH - FILL PIPE @ 4333' & SHOE .50 BREAK CIRCULATION AND REAM BRIDGES AT 8618' AND 8809' .50 TIH .50 REAM FROM 9276~ TO 9370' 5.00 ROTARY DRLG FROM 9370' TO 9415' NOTE; GAINED 12 BBL ON TR~.__(.~6TEE2~ IADC BIT GRADE BIT #7 - 6-8-LT/BT-A-E-6-RG-TQ NOTE~ PLEASE REMEMBER TO SEND IN YOUR MAN HOURS_~G_.:..~ TO LARRY LITTLE (SUEPI SAFETY TECH2 @ 776-2518 - THANKS LAST BOP TEST ~L~E/9~ LAST CSG TEST ~8_~Z/9~ BHA INSPECTION (CUM. ROT HRS) PPi @ KILL SPEED 1240 @ 40 PP2 @ KILL SPEED 840 @ 20 T I M E_..~._H R S2 CUM. ROT. HRS 150.25 ROTATING 13.50 MUD MOTOR TRIPPING 7.00 C & C 1.00 REAMING 1.00 SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 1.50 INSPECT BHA RIG UP/TEAR DOUN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: WELLS R V PROG. DEPTH 12170 PRESENT DEPTH 9530 FOOTAGE DRILLED 115 SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 WATER DEPTH 80 /GALLOWAY DR PRESENT ACTIVITY: JUST GETTING ON BOTTOM SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 12.50 DRILL ~9415' !~9530' WL~IT #8 1.00 DROP DUAL SINGLE SHOT SURVEY TOOLS. 10.50 TRIP F/N_..~EW:~)I'._~ET!ING ON BOTTOM AT RPT TIME. BIT #8 COND: 2-3-WT-A-E-I-LT-TQ/HRS__ ELEVAT. KB TO MSL 116.0 DATE ~8__~/'9~ DIST. KB TO BHF 38.4 DAY 25 NLTA LTH/YTD / EST. DAY 45 LTA LTH/YTD ___/___ DAYS +/- DAYS SINCE LAST LTA 876 LAST BOP TEST ~Z~E/9~ LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 1000 @ 20 PP2 @ KILL SPEED 1375 @ 40 CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 162.75 12.50 ~0.50 1.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: DROPPING SURVEY PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE ~8.8_8/_~/9 PRESENT DEPTH 9755 DIST. KB TO BHF 38.4 DAY FOOTAGE DRILLED 225 NLTA LTH/YTD / EST. DAY SIZE OF LAST CSG 7.000 LTA LTH/YTD / DAYS +/- . DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA ~7._Z ~ATER DEPTH 80 LAST BOP TEST ~8__~E/9~ LAST CSG TEST /GALLOWAY DR BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 850 PP2 @ KILL SPEED 1260 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 24.00 ROTARY DRILLING FROM 9530~ TO 9755' PREPARING TO DROP SINGLE SHOT SURVEY AT REPORT TIME. NOTE: DAILY COSTS INCLUDES $20M OF 5" CASING COSTS - CUTTING STL THREADS. T LNE.~URS2 _ CUM. ROT. HRS 186.75 ROTATING 24.00 MUD MOTOR TRIPPING C&C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS .... o~EPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM hA" UELL A41A-11 UORK ORDER 739930 SIDE TRACK PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE PRESENT DEPTH 9755 DIST. KB TO BNF 38.4 DAY 27 FOOTAGE DRILLED NLTA LTH/YTD .___/___ EST. DAY ._~4~ SIZE OF LAST CSG 7.000 LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 878 MATER DEPTH 80 LAST BOP TEST ~8/~!/9~ LAST CSG TEST DRILLING FOREMAN: UELLS R V / PRESENT ACTIVITY: gASHING/REAMING AT ~i81' SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : 1.00 DROP DUAL SINGLE SHOT SURVEY TOOLS. BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED ~ @ ._~ PP2 @ KILL SPEED ~ @ 5~ 3.50 ~N=W/__~T_#9,_LAST 20 STDS CAME MET. 1.50 STAND HUDP BACK ON LEFT SIDE OF DERRICK, L_.~./_~_JA~, STAB~_BITSU~ BI~= 4.00 DID WEEKLY BOPE'TEST. 1.00 MAKE UP NEW_~BHA MOTOR ASSMY U/MUD. 3.50 [I~. FILLED PIPE AT 3950~ AND AT SHOE. 1.00 TAG UP AT 8376',_mM/U TOP ~IVE, PACK~p OFF STUCK. UOR~[~/JARED LOOSE. PULLED UP T/823~~ W/MANY TIGHT SPOTS. 1.50 ~IRC/COND MUO~ W~RK AND ROTATE STRING AT 8237~ TO 8200~. 7.00 [EAM~WAS~ F/8237~ T/9181~. DRILLED THRU BRIDGES AT 8476~ AND 8540~. GOING BETTER BELOU 8540~ BIT #9 COND: 4-4-BT-A-~F.(.~3)-I-ER-HRS TIME ~RS2 CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C&C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/UH TESTING BOP /UH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 186.75 9.50 1.50 7.00 1.00 1.00 4.00 S~EPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM #A FIELD MIDDLE GROUND SHOAL LEASE PLATFORM UELL A41A-11 UORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: WELLS R V PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE ~9/~/9~ PRESENT DEPTH 9798 DIST. KB TO BHF 38.4 DAY 28 FOOTAGE DRILLED 44 NLTA LTH/YTD ~_/___ EST. OAY 45 SIZE OF LAST CSG 7.000 LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 879 MATER DEPTH 80 LAST BOP TEST ~8/~/9~ LAST CSG TEST ~8_~/9~ / BHR INSPECTION (CUM. ROT HRS) PRESENT ACTIVITY: DRILLING AHEAD ~BIT #11 PP1 g KILL SPEED PP2 a KILL SPEED SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : 3.50 FINISHED REAMING F/9~81' T/9755'. TOOK MUD SURVEYS A~=~466'~ 95~.c___ 9659~ AND AT 9755~. ~BIT DEPTHS~. 5.0~ ATTEMPTING TO SLIDE/ROTARY DRILL F/9755' T/9778' U/BIT #10. UNABLE TO MAINTAIN MWD SIGNAL LONG ENOUGH TO SLIDE. 12.00 PULLED T/SH~Ez DROP BAR AND SHEAR OUT PUMP-OUT SUB, PUMP PILL, POll.___ LAY DOWN 'M~D~_..~FOUND SEVERAL PIECES OF COAL JAMMING TOOL) MAKE UP 30~ DROPPING ASSMY. T~H. FILL PIPE AT 3950~ AND AT SHOE. CIRC AND SHEAR MUD AT SHOE WHILE SERVICE RIG AND TOP DRIVE. RUN ON IN ~p~Ez REAM THRU BRIDGE AT 8885~ T/8890~. (HAD LEDGES/BRIDGES AT 834~.~ 8885~ AND 9783~ 3.50 DRILL F/9778~T~7~' W[BIT #11. BIT #10 COND: 2-2-WT-A-E-I-CT-MWD (DEBRIS IN MUD) 980 @ 30 1400 @ 50 T [ ME [HRS~ CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/UN TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOUN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON UEATHER/MAT EVALUATION CORING OTHERS 195.25 6.50 2.00 12.00 3.50 SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORH UELL A41A-11 ~ORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: ~ELLS R V / PRESENT ACTIVITY: T_.J.[H_._~fOVERSHOT ASSMY PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE ~9_.~/9~ PRESENT DEPTH 9825 DIST. KB TO BHF 38.4 DAY 29 FOOTAGE DRILLED 27 NLTA LTH/YTD / EST. DAY 45 SIZE OF LAST CSG 7.000 LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 880 UATER DEPTH 80 LAST BOP TEST ~8.8_~/9~ LAST CSG TEST ~8/~Z/9~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED PP2 a KILL SPEED SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : 4.00 DRILL [/9798' T_,/9825' ~B~T ~11 : _ 4.00 TUISTED OFF. PULLED T/SH~_PUMPPILL POH. RECOVERED 8520' OF STRING. LEFT IN HOLE; 105~ OF BH~z A~.NOTED ON YESTERDAYS REPORT AND 1200~ OF ~112" DRILL PIPE. TUISTED OFF JT gAS 24.88' LONG. FAIRLY CLEAN BREAK IN PIPE BODY. [40 JTS AND A 5~ STUB OF DP LEFT IN HOLE PLUS THE BHA~__ 4.50 ~/LI_~IS~NG ASSMY TIH T/7889~ TAGGED UP. 1.50 ~AS~[RE6~F/7889' T/8491'. MANY BRIDGES TO REAM THRU. 1.50 CIRC HOLE CLEAN PRIOR TO ATTEMPT ENGAGING FISH. LOTS OF LARGE PIECES OF COAL RECOVERED OVER SHAKERS. 1.50 UORKED DOUN TO FISH, TAGGED IT AT:~31'. ATtemPT TO ENGA_.~GE F___~SH~ DI__D _ NOT HAVE SUCCESS. 1.00 CIRC HOLE CLEAN ABOVE FISH. 3.00 POH U/OVERSHOT ASSSMY. LIP GUIDE UAS BENT. LAY DOUN LIPGUIDE. TIME ~H__RS CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOkrN /BOP/IJH TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DOUN DS INSPECT BHA RIG UP/TEAR DO,IN UAIT ON UEATHER/MAT EVALUATION CORING OTHERS 3.00 U/U_~AL___~L_HO~[.,__~_3/4" AND ADJUST KNUCKLE JT T/ORIENT u_~./_.H_~oI(.:T~~ AT __ REPORT TIME. @ 30 @ 50 199.25 20.00 SI4EPI ALASKA DALLY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "Am' gELL A41A-11 UORK ORDER 739930 PROG. DEPTH 12170 PRESENT DEPTH 9825 FOOTAGE DRILLED SIZE OF LAST CSG 7~000 DEP. OF LAST CSG 7765 SIDE TRACK gATER DEPTH 80 DRILLING FOREMAN: ~ELLS R V / PRESENT ACTIVITY: CIRCL~.OND F/SHORT TRIP SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : 3.00 [I__H.HT_~,T/_~,~OE U/IJA.LLHOOK ASSMY 1.00 SLIP/CUT DRILLING LINE 100'. ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY 30 NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 881 LAST BOP TEST ~8/'~!/~~ LAST CSG TEST 08/0~_.~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 620 a 20 PP2 @ KILL SPEED 1020 a 40 4.00 GO INTOOPEN HOlE U~RK PAST/THRU LEDGES~RIDGES T__/8310. UNABLE TO GET DEEPER. 7.00 POH.,._.LA__~.Y DOUN FISHING ASSMY. M/U~CL~6~OUT ASSM~. TIH=_TAG UP AT 8185'. 6.00 CLEAN OUT BRIDGES/UORK OVER LEDGES F/8185' T/8531' TOP OF FISH. 3.00 MIX AND PUMP 15.0 PPG VISCOUS 40 BBL PI~L,__~IRGZCOND FOR SHORT TRIP. T I ME iH CUM. ROT. HMS 199.25 ROTATING MUD MOTOR TRIPPING 10.00 C & C 3.00 REAMING ~0.00 SURVEYS JET REPAIRS FISHING NIP UP/DOi,/N /BOP/IJH TESTING BOP RUNNING CASING CEMENTING ~__ PICKUP/LAY DOUN DS .... INSPECT BHA .... RIG UP/TEAR DOUN .... ~/AIT ON ~EATHER/MAT .... EVALUATION .... CORING £PI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: FLUSH OUT BHA ELEVAT. KB TO MSL 116.0 DATE ~9/~/9~ DIST. KB TO BHF 38.4 DAY 31 NLTA LTH/YTD ___/___ EST. DAY ._~4~ LTA LTH/YTD ___/___ DAYS +/- DAYS SINCE LAST LTA ~8~2 LAST BOP TEST ~8/~/9~ LAST CSG TEST ~8/0~/9~ PROG. DEPTH 12170 PRESENT DEPTH 9825 FOOTAGE DRILLED SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 WATER DEPTH 80 BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED PP2 @ KILL SPEED T ! M E ~.H_.RS~._ CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C &C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOUR /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOUR WAIT ON WEATHER/MAT EVALUATION CORING OTHERS SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.50 FINISHED CIRC/CO~D~$HORT TRIP AND PULLED.T/SHOE. 1.50 SERVICE RIG. CHECKED OUT BRAKE BLOCKS ON DWKS, READJUST BLOCKS. 1.50 TIH T/TOP OF .FISH, gASH/~.EA~_T/~531~. 4.50 ~IRC/COND MIX AND PUMP HI VIS 15 PPG SWEEP. .._Z~ pOH,_MAKE UP SHORTER gALL HO~OK_.z__~/BORED OUT I.D.s__pR OVERSHQL.. TIH. 1.00 ~U:TOP DRIVE~ ~ORK PAST SEVERAL LEDqES.~._E__NGAGED FISff, INSIDE OF FISH WAS PLUGGE~.~._.~_~UN~BLE TO CIRC. 5.50 NIT JARS 1LICK~:FISH:FREE,_~UL~D_.UP ~WALLHO~ BACKED OFF OVERSHOT AND WALLHOOK ASSMY,:LAYED OO~_~:STUB OF PARTED DRILL PIPE AND TOOLS. 1.50 POH_~/REST O'F___~STRI___~N~. BROKE OFF BIT AND UNPLUGGING BHA AT RPT TI.ME. @ 20 @ 40 199.25 24.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "'A" WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: WELLS R V / PRESENT ACTIVITY: TI.H ~/WALLHOOK-OVERSHOT ASSMY ELEVAT. KB TO MSL 116.0 DATE ~9/0~/_~ DIST. KB TO BHF 38.4 DAY 32 NLTA LTH/YTD / EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA' 883 LAST SOP TEST ~8_~/9~ LAST CSG TEST ~8_.~/9~ PROG. DEPTH 12170 PRESENT DEPTH 9846 FOOTAGE DRILLED SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 WATER DEPTH 80 BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED PP2 @ KILL SPEED SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.50 TIH ~/_.~.6, FLUSH. OUT U/MU~ PUMPS. POH. 5.00 MAKE UP NEW BIT ON B~A. TIH. TAGGED UP AT 8770'. 3.00 gASH/REAM THRU BRIDGESLE/_L~.~_~S F/SFTO' T/9825~ 4.50 DRILLING W~BIT #12 F/9825~ T~9846~. 3.50 TUISTED OFF. POH. RECOVERED 8440~ OF DRILL PIPE. TOF IS 8440~. FISH IS ~IT #12~_~F~L~6T, MO~EL pC. NH_..~TAB,_MON~.D~,f_~.STAB.z_.DA~[EY _ ~ARS.~.~._~.3~_JTS ~DP, p..o, S~,~.11JTS DRILL PIPE AND A 25.33' STUB OF DP 1.50 ~IP/~U~ ~IL~IN~ L~NE. SERVICE_~IG. 4.00 MAKE UP FISHING TO0~. TI~ AT RPT TIME. RECONITIOR TO ALL THE WEATHERFORD FOLKS WHO WORKED THRU THE LABOR DAY WEEKEND GIVING US EXCEPTIONAL SUPPORT DURING OUR FISHING JOB. CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING I,c&c REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOUN /BOP/UH TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DOUR DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS @ 20 @ 40 203.75 4.50 15.00 3.00 S~EPI ALASKA DAILY DRILLING REPORT! PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM UELL A41A-11 UORK ORDER 739930 SIDE TRACK DRILLING-FOREMAN: WELLS R V PRESENT ACTIVITY: JAR ON FISH TOP AT 8440r PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE PRESENT DEPTH 9846 DIST. KB TO BHF 38.4 DAY ~3~ FOOTAGE DRILLED NLTA LTH/YTD / EST. DAY ~4~ SIZE OF LAST CSG 7.000 LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA WATER DEPTH 80 LAST BOP TEST ~8_~L~ / BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 750 @ 20 PP2 @ KILL SPEED 1350 @ 40 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.00 FINISH TIH ~/WALLHOOK ASSMY T/8440~ TOF.__ 1.50 ATTEMPT TO WORK OVER AND ENGAGE FISH, NO SUCESS. 9.50 ~. LE~_Ir OF THE WALLHOOK IN THE HOLE. CONTROL RING HAD BEEN RUN ON INSTALL NEW CONTROL GUIDE RING W/pLUSTERITE FACE_j_NE~._~.U~LH991(~. TIH. 1.00 [~UNp_TOF._MILLED~O~ER TOP. E~GED FIS~.__ 10.00 JAR ON_FISH, PUMPED AH~-V..~:.~.L~EIGHT 40 BBL PILL AROUND. INDICATIONS ARE WE ARE CIRC THRU THE BIT AS WELL AS THE OVERSHOT ~WHICH DOES NOT HAVE .A PACK-OFF DUE TO WELDING THE CLUSTERITE.) DIA-LOG WILL BE ON THE FIRST AVAILABLE HELICOPTER TO BACKOFF AS DEEP AS WE CAN BELOW OVERSHOT TIME ~.H~RS 2 CUM. ROT. HRS 203.75 ROTATING MUD MOTOR TRIPPING C &C REAMING SURVEYS JET REPAIRS TESTING BOP /WH RUNNING CASING CEMENTING ____~ PICKUP/LAY I~OWN DS · INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION ~_ CORING OTHERS SgEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" PROG. DEPTH 12170 FIELD MIDDLE GROUND SHOAL PRESENT DEPTH 9846 LEASE PLATFORM "A" FOOTAGE DRILLED WELL A41A-11 SIZE OF LAST CSG 7.000 WORK ORDER Z~ DEP. OF LAST CSG 7765 SIDE TRACK UATER DEPTH 80 DRILLING FOREMAN: gELLS R V / ELEVAT. KB TO MSL 116.0 DATE ~9_~/9~ DIST. KB TO BHF 38.4 DAY ._~3~ NLTA LTH/YTD / EST. DAY .~4~ LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 885 LAST BOP TEST ~L~/9~ LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PRESENT ACTIVITY: ATTEMPTING BACKOFF AT 9680~ SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 4.00 JAR ON FISH WHILE WAITING ON DIA-LOG. PP1 @ KILL SPEED 750 @ 2~ PP2 @ KILL SPEED 1340 @ 40 20.00 RIG UP DIA-LOG. RAN FREEPOINT AND 600 GRAIN STRING SHOT. UNABLE TO GET PAST TOP OF DRILL COLLARS AT 8220~. POH REDUCED SPRING TENSION ON TOOLS. RAN IN HOLE ~UMPOUT SUB AT 88~UNABLE TO WORK BELOU THERE. PIPE IS FREE 8803~. PO~_TOOK ALL SPRING TENSION OUT OF TOOLS. RIH ~FREE POIN[/_.~TRING SHOT COMBO. FREE POINT IS 2ND JT ABOVE THE JARS AT 9680'. PULLED UP T/NEAR SURFACE_~/_~_~~LS.:~O~R~ELLEFTHAND TORQUE~_~- TURNS DOWN_~.~L~T OUT 1 TURN~ RUN IN HOL~_~/S~T__~Z96__.~8~_L ADD 1 TURN SIGNAL SHOT TO FIRE; NO SURFACE INDICATIONS OF A BACK-OFF. POH WITH TO~ SHOT DID NOT FIRE. BUILDING SHOT #2 AT RPT TIME. MR. BLAIR WONDZELL OF AOGCC APPROVED POSTPHONING BOPE TESTING UNTIL DONE FISHING. T I ME~_H R~S)_ CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C &C REAM I NG SURVEYS JET REPAIRS FISHING NIP UP/DOIJN /BOP/WH TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 203.75 24.00 SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" UELL A41A-11 UORK ORDER 739930 SIDE TRACK DRILLING FOREMAN-: UELLS R V PRESENT ACTIVITY: J__~AR__/~ORK ON FISH AT 9680' PROG. DEPTH PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 WATER DEPTH 80 / 12170 ELEVAT. KB TO MSL 116.0 DATE ~L~L~ 9846 DIST. KB TO BHF 38.4 DAY 35 NLTA LTH/YTD / EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 886 LAST BOP TEST ~L~/9~ LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED @ 20 PP2 @ KILL SPEED @ 40 SUMMARY OF OPERATIONS (SHO~ HOURS FOR EACH OPERATION) : 4.50 FINISHED BUILDING NEW 600 GRAIN STRING SHOT. NIH ~/DIA-LOG T/9680' DP MEASUREMENT...9711' ~IRELINE MEASUREMENT. HAD 9 TURNS LEFTHAND TORQUE ]~_S~RIE~, F,IRED .SHO],=HADPOSI[[VE_~UR[6CE INDICATIONS OF BACKOFF. 12.00 gORK MORE LEFTHAND TORQUE DOgN TO FINISH UNSCREUING AT 9680'. PULLED 325K TO GET STRING MOVING OUT OF ITS "RUTS" FROM JARING. POH~L~ED DOUN FISHIN~L_.~.SRECOVE____RED 25' TWISTED OFF JOINT OF ~1/~'Z.._~DE~.11 ~=~P,:~JTS 0F.3 1/2~ HUD~,_PO SUB. ~MOVED THE 11JTS RECOVERED AND 3 STANDS ABOVE FISHING TOOLS UP INTO MIDDLE OF THE STRING UHERE IT gILL BE IN TENSION AT ALL T]MES~ MAKE UP SCREU-IN SUB ON BSZ~ .... 18 ~ ACCELER~ATO~,_9_~DP_cTIH T~80~._~D__[O ~ASfl.~J~ORK 10' THRU BRIDGE, ~ASH[~ORK THRU BRIDGE A[_91~z__~9132_~OT ~UCH PROBLEM THO. 3.00 CIRC/COND HOLE~MUD PRIOR TO ENGAGING FISH. 4.50 SCREU INTO FISH AT 9680_..~.z....~BL[_TO_~IRC~J~UORK ON FISH. TIME (_.HRS.~ ....... CUM. ROT. HRS 203.75 ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING 24.00 NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOUR DS INSPECT BHA RIG UP/TEAR DOWN UAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" ~ FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" UEI. L A41A-11 ~ORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: UELLS R V PROG. DEPTH 12170 PRESENT DEPTH 9846 FOOTAGE DRILLED SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 ~ATER DEPTH 80 / PRESENT ACTIVITY: ~IR_._~CL~ON~._~JA~R ON FISH ELEVAT. KB TO MSL 116.0 DATE ~9/~/9~ DIST. KB TO BHF 38.4 DAY 36 NLTA LTH/YTD / EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 887 LAST BOP TEST ~L~/9~ LAST CSG TEST gS_L~Z/9~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED @ 20 PP2 @ KILL SPEED @ 40 SUMMARY OF OPERATXONS ($HOU HOURS FOR EACH OPERATION) : 2.00 JAR ON FIS~,.UN~BLE TO CIRC. 13.00 RIG'UP D[A-LOG, MADE DRIFT RUN T/~' ABOVE ~IT SU~.~_~.9839~=._PLUGGED SOLID THERE. PO~ MAKE UP 5 SHOT PERFORm[OR, NIH. PERF 9829, T__~32~__ POH~ RIG DIA-LOG ASIDE. 2.50 ATTEMPT TO CIR._____~C.~_.~_.NO SUCESS. JAR ON_[]S~,_~I~XNG JARS FADING FAST..NOU APPEARS THAT THE DRILLING JARS HAVE STARTED HITTING NOU[ VERY HARD TOO 5.50 RIG DIA-LOq._~/5 SHOT PERFORATOR, RIH AND PERF 3' BELOU THE TOP STAB AT 9780~T/9783~. PO~.c_~J..~IG DIA-LOG ASIDE. 1.00 MAKE UP CIRC LINE, ESTABLISH CIRCULATION! ClRC/COND AND ALTERNATLY JAR ON FISH...JARS HITTING VERY HARD AT THIS_TI~E_z ~ORKING GOOD. T X M E .~.11R SI_ CUM. ROT. HRS 203.75 ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOUN /BOP/UH TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DOUN DS INSPECT BHA RIG UP/TEAR DOUR UAIT ON UEATHER/MAT EVALUATION CORING OTHERS 24.00 £PI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: WELLS R V PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE PRESENT DEPTH 9777 DIST. KB TO BHF 38.4 DAY 37 FOOTAGE DRILLED NLTA LTH/YTD / EST. DAY 45 SIZE OF LAST CSG 7.000 LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 888 WATER DEPTH 80 LAST BOP TEST ~!~_~ LAST CSG TEST __/ BHA INSPECTION (CUM. ROT HRS) PRESENT ACTIVITY: JARING O~FI~.~_ SEVERED AT 9777 PP1 @ KILL SPEED PP2 @ KILL SPEED SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 5.50 JAR ON FISH: CIR~LCOND MUD. 2.00 PUMP PILL.z_.~~ DOWN CIRC LINE. RIG UP DIA-LOG. 9.00 RIH ~/5 SHOT PERFORATOR AND SHO~T 9815~T/9818'. JUST BELOW BOTTOM STAB ~OH. MAKE UP 600 GRAIN STRING SHOT/FREE POINT COMBO TOOL~R~H. TOOK FREE POINT REA_..~DINGS~ TORQUE ONLY. TO~L WOULD NOT SET PROPERLY IN THE MONELS FOR STRETCH READINGS. APPEARED TO HAVE A LITTLE WIGGLE JUST BELOW THE TOP STAB AND SAME AT BOTTOM OF TOP MONEL DC. PULLED TOOLS ~P T/1500~, TORQUED STRING TO 14 TURNS RIGHT HAND TORQUE TO TIGHTEN STRING THEN WORKED 9.5 TURNS LEFT HAND TORQUE DOWNHOLE. RIH ,~/COMBO TOOLS. FIRED STRING SHOT AT 9807~. NO SURFACE INDICATIONS OF A BACKOFF PO~~L~.~__~.~HOT HAD FIRED OK. WORKED STRING T_~O_BAC~KOF.___~F~ NO~SUFESS. 1.50 UORK STRING WHILE BUILDING DIA-LOG SEVERING SHOT. 3.00 RIH ~_.~fSEVERING TOOI.~E.RED BHA AT THE BOTTOM OF THE TOP STABS PIN. 9???'.~P~H WL~IA-LOG TOOLS. ).00 CIRC AND JAR ON FISH...UE ARE SEVERED AT BOTTOM OF THE STAB SCREWED ONTO THE JARS THAT ARE WORKING GOOD. SPOT FRESH #4 DIESEL AROUND FISH PUMP 30 BBLS AT I BBL EACH MIN AT RPT TIME. 1340 @ 20 1780 @ 40 T I M E .~._~ R S1 CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /UN RUNNING CASING CEMENTING PICKUP/LAY DOUX DS IXSPECT BXA RIG UP/TEAR DO~X WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 203.75 ~4.00 RIG NAME PLATFORM hA" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM #An WELL A41A-11 WORK ORDER 739930 SIDE TRACK SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE ~9.~_~/9~ PRESENT DEPTH 9724 DIST. KB TO BXF 38.4 DAY 38 FOOTAGE DRILLED -~_ XLTA LTX/YTD / EST. DAY 45 SIZE OF LAST CSG _7._:.~ LTA LTH/YTD _~/_~ DAYS +/- ~- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 889 ~-- WATER DEPTH 80 LAST BOP TEST ~8/~!/9~ LAST CSG TEST ~8_L0_~7/9~ DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: SHORT TRIPT/SHOE SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.00 JAR ON FISH. FINISH PUMPING #4 DIESEL AROUND FISH AT 1 ~/MIN STAGES. 6.00 RIG UP DIA-LOG, WORK 9 TURN OF LEFTHAND TORQUE INTO STRING, LET OUT 2. ~IH=g/600 GRAIN STRING SHOT_]~TOP OF DAILEY JARS AT 9741~. PUT IN THE 2 TURNS OF LEFTHAND TORQUE. FIRED SHOT. PO~_W/DIA-LOG AND LAY DOWN TOOLS/RIG THEM DOWN. BACKED OFF AT 9741~ OK. 9.5~ POH, LAYED DOWN 2 JTS HWDP RECOVERED FISH. MAKE UP CLEANOUT BH~L TAG BRIDGE AT 8792~. BXA IXSPECTIOX (CUM. ROT HRS) PP1 @ KILL SPEED 8._~7~ @ ..~2~ PP2 @ KILL SPEED !~ @ 40 ~ BROKEN WALL HOOK TO THERE. GOOD DEAL IF DID, gILL CEMENT IT IN PLACE. ._~0..~0 ~IR~/COND FOR SHORT TRIP MUD NEEDS QUITE A BIT OF WORK ON IT AFTER ALL 1.50 WAS~/REAM THRU TIGHT SPOTS AT 8792~ AND 9653~. CLEANED OUT T/9724~ ENCOUNTERED TORQUIE CONDITIONS THERE. POSSIBLE PUSHED THE 1~ OF ~ ~L~_.~" THE TRIPS FISHING AND HAVENT CIRC MUCH TO KEEP IT IN CONDITION. PUMP PILL._~LL_PUL..__~.L_.T_/SHOE AT RPT TIME. HOLE IN GOOD CONDITION COMMING OUT LOST IN HOLE EQUIPMENT ANADRILL: 2-4 ~4" MONEL DC'_~S~I STEEL nQUICK CHANGEm S~AB_~.. I NM STAB. SER #'S: 3797~ 570~ ...... 137 ....................... 60~6 .... DAILEY: 1 SET 4.__~[4- JARS SER #1400-1174 _ __ WEATHERFORD: 1-~'_~__/4" BIT SUB SER #30546 TODAYS COST REFLECTS LOST IN HOLE EQUIP AND DIA-LOG~S COST; $98~000 TIME_£~RS2 CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING Ic&c REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BNA RIG UP/TEAR DOUX WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 203.75 10.50 1.50 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: TRIPPING PROG. DEPTH 12170 PRESENT DEPTH 9394 FOOTAGE DRILLED SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 WATER DEPTH 80 / ELEVAT. KB TO MSL 116.0 DATE ~9_~!~/9~ DIST. KB TO BHF 38.4 DAY 39 NLTA LTH/YTD / EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 890 LAST BOP TEST ~8/]~/9~ LAST CSG TEST ~8/~Z/9~ BHA INSPECTION (CUM. ROT HRS) PPi @ KILL SPEED 860 @ 20 PP2 @ KILL SPEED 1260 ~ 40 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 4.50 RIG REPAIR - CHANGE OUT BRAKE BANDS 1.50 TIH 3.50 'cIRc & CONDITION MUD (COULD ONLY PUMP 40 SPM2 4.00 TOOH 1.00 BHA 4.00 TIH W/OPEN ENDED DRILL PIPE 2.50 CIRC & CONDITION MUD (CHANGE SHAKER SCREENS TO 2.00 HOLD PRE-JOB SAFETY MEETING - PUMP 8 BB~=~4 DIESEL,_~_BBL SOAPY H20.L__ 100 SX CLASS G CMT W/.6%=CFR2 & .p6~ HR5. 1.4B~.SOAPY H20.~_& 1:4 BBL #4 D~L. ~.5_~BL. 11.4 PPG MUD - EST TOP OF CMT 9394' - CMT IN PLACE · 0454 HRS. 1.00 TOOH NOTE; WELL FLOWING 1/3 BBL PER HR. ..... CUM. ROT. HRS 203.75 ROTATING MUD MOTOR TRIPPING ~0.50 C & C 6.00 REAMING SURVEYS dET REPAIRS 4.50 FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING 2.00 PICKUP/LAY DOWN DS 1.0.0 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: WASH & REAM PROG. DEPTH 12170 PRESENT DEPTH 9394 FOOTAGE DRILLED SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE ~!E/9~ DIST. KB TO BHF 38.4 DAY 40 NLTA LTH/YTD / EST. DAY 45 LTA LTH/YTD _~/___ DAYS +/- DAYS SINCE LAST LTA 891 LAST BOP TEST ~9_.Z:~/9~ LAST CSG TEST ~/9~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED @ 20 PP2 @ KILL SPEED @ 40 LAY DOWN BAD JTS .50 RIG REPAIR ~_IRON ROUGHNECK2 2.50 FINISH TOOH W/D~LL PIPE - NOTEI LAYED DOWN 16 JTS WITH WORN HARDBAND AHD 9 JTS WITH MIN. PIN OD 2.5~ ~U HWDP OFF RACK - CIRC 4.50 PULL WEAR BUSHING - TEST BOPS Z.O0 BHA - M/U MOTOR & MWD 6.00 TIH - FILL PIPE g 4500~ & SHOE 1.00 WASH &-REAM NOTE~ WELL DID NOT FLOW WHILE TESTING BOPS FIRE ALARM SOUNDED g 1430 HRS - gELDER WORKING UNDER BAY 6 - LIGHT REFLECTED TO FIRE EYE & SET OFF ALARM - ALL PERSONNEL RESPONDED. T I ME [URS2 CUM. ROT. HRS 203.75 ROTATING MUD MOTOR TRIPPING 13.50 C & C REAMING 1.00 SURVEYS JET REPAIRS .50 FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH 4.50 RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 4.50 INSPECT BHA RIG UP/TEAR DOWN UAIT ON WEATHER/MAT EVALUATION CORING OTHERS SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : 5.00 TOOH W/OPEN ENDED DRILL PIPE - INSPECT DRILL PIPE HARDBAHD & PIN OD - RIG NAME PLATFORM aaa FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A41A-11 WORK ORDER 739930 . · ~EPI ALASKA DAILY DRILLING REPORT PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 PRESENT DEPTH 9587 DIST. KB TO BHF 38.4 FOOTAGE DRILLED 87 NLTA LTH/YTD /___ SIZE OF LAST CSG 7.000 LTA LTH/YTD / DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 892 PAGE 1 OF 1 DATE ~L~/9~ DAY 41 EST. DAY 45 DAYS +/- SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: DRILLING WATER DEPTH 80 / SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.00 gASH RE~M, & DRLG CMT TO 9499' .50 CIRC & CONDITION MUD 10.00 TIME DRILL OFF PLUG FROM 9499' TO 9519~(LO~_U~T) 11.50 SLIDE & ROTARY DRLG FROM 9519' TO 9587' NOTEZ TOOK ON 30.000 GAL DIESEL FROM MV MONARCH BACKLOADED MISC. DRILLING EQUIPMENT TO MONARCH LAST BOP TEST '~9/!~/9~ LAST CSG TEST ~8_~Z/9~ BHA INSPECTION CCUM. ROT HAS) PPi @ KILL SPEED 1080 @ 20 PP2 ~ KILL SPEED 1825 @ 40 UNLOADED MISC. DRILLING SUPPLIES FROM MONARCH NOTE; LOg RATE OF PENETRATION ON BIT #13 DUE TO TIME DRILLING OFF CMT. PLUG - PENETRATION RATE AT REPORT TIME APPROX. ?~.~HR T I M E .(.HRS.). CUM. ROT. HAS ROTATIHG MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOk/N /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOI./N DS INSPECT BHA RIG UP/TEAR DOWN UAIT ON WEATHER/MAT EVALUATION CORING OTHERS 225.25 7.50 14.00 .50 2.00 SUEPI ALASKA DALLY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM aA" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A# WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: TRIPPING PROG. DEPTH 12~70 ELEVAT. KB TO MSL 116.0 DATE ~9/1~/_..y.~ PRESENT DEPTH 9683 DIST. KB TO BHF 38.4 DAY FOOTAGE DRILLED 96 NLTA LTH/YTD / EST. DAY 45 SIZE OF LAST CSG _7._:..~.~ LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 7~6_.~5 DAYS SINCE LAST LTA 893 WATER DEPTH 80 LAST BOP TEST ~/~/_~ LAST CSG TEST ~8/~/~ / BHA INSPECTION (CUM. ROT HRS) PPl a KILL SPEED 1020 ~ 20 -- _ SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : ~.00 ROTARY DRLG. U/MUD MOTOR FROM 9587~ TO 9615~ 4.50 ORIENT ~ SLIDE FROM 9615' TO 9645' 6.00 ROTARY DRLG. Y/MOTOR FROM 9645' TO 9683' PP2 a KILL SPEED 1640 @ 40 . NO.__.._~.T[; UHILE MAKING CONNECTION g 9683' SAVER SUB FAILED WHEN PICKING UP STRING. DRILL STRING FELL APPROX. 6' AND WAS CAUGHT BY -ELEVATORS. 2.00 TOOH TO SHOE - TIGHT SPOTS g 8850'.__843~ 8420~ 2.00 RIG REPAIR - CHANGE OUT SAVER SUB 2.50 PUMP PILL & TOOH FOR BIT & BHA CHANGE ~_ NOTE~ FIRE ALARM SOUNDED @ 0940 HRS - WHR #3 FIRE EYE - ALL PERSON- NEL RESPONDED - DO NOT KNOW WHAT SET OFF EYE? NOTE~ UELL DID NOT FLOU UHILE SHUT DOUN REPAIRING SAVER SUB. -------- ,__~.N~TE.~ POOR OVERALL P" RATE ON BIT #13 DUE TO TIME DRILLING OFF CMT. PLUG. TIME CUM. ROT. HAS ROTATING MUD MOTOR TRIPPING Ic&c REAMING SURVEYS ~ET REPAIRS FISHING NIP UP/DOWN /BOP/UH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOUN DS INSPECT BHA RIG UP/TEAR DO~N WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 242.75 13.00 4.50 4.50 2.00 SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM aaa UELL A41A-11 UORK ORDER 739930 SIDE TRACK ORILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: DRILLING PROG. DEPTH PRESENT DEPTH FOOTAGE DRILLED 54 SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 UATER DEPTH 80 / 12170 ELEVAT. KB TO MSL 116.0 DATE ~9_/!~/_~.~ 9737 DIST. KB TO BHF 38.4 DAY 43 NLTA LTH/YTD ___/___ EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 894 LAST BOP TEST 0~/13/95 LAST CSG TEST 08LOTL95 BHA INSPECTION (CUM. ROT HAS) PP1 @ KILL SPEED 120~ @ 20 PP2 @ KILL SPEED 1850 @ 40 SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : .50 TOOH ~LAST 20 STD UET) 2.00 BHA - L/D 1.5 DEG. MOTOr. S~AB'S~.& ~ON~L COLLA,~:~ ~/U 1.25 DEG. MOTOR & MOREL FLEX JTS. 1.00 TEST MUD - NO UORK - PULL - REPAIR - INSTALL .50 BHA - P/U JARS & TEST MUD 1.00 RIG REPAIR - BOLTS ON UEAR PLATE ON PIPE HANDLER LOOSE - CHG. OUT BOLTS & SAFETY UIRE SAME. 2.50 TIH TO 5130' - FILL PIPE & CHECK MUD 1.00 PLATFORM POUER FAILURE 2.00 TIH - FILL PIPE a SHOE - TIH TO 9609' .50 REAM TO BOTTOM 1.50 ROTARY DRILL U/1.25 DEG. MOTOR FROM 9083' TO 9689' .50 CIRC & CONDITION MUD 10.00 DRLG. FROM 9689~ TO 9735' .50 SURVEY (MU~:JAMNED_~_~._~OR__.[_KP_.[.[P_[E. GgT SURVEY~ .50 DRLG. FROM 9735' TO 9737' IADC DULL GRADE BIT #13 - 4-6-RG-H-E-I-ER&BT-RIG&HRS CUM. ROT. HAS 254.75 ROTAT I NG 12.00 MUD MOTOR TRIPPING 5.00 C & C .50 REAHING .50 SURVEYS .50 JET REPAIRS 2.00 FISHING NIP UP/DOUR /BOP/UH TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 3.50 INSPECT BHA RIG UP/TEAR DOUR UAIT ON UEATHER/MAT EVALUATION CORING OTHERS SUEPI ALASKA DAILY DRILLING REPORT PAGE I OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM UELL A41A-11 UORK ORDER 739930 SIDE TRACK .. ORILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: DRILLING PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE 09/1~/~ PRESENT DEPTH 9853 DIST. KB TO BHF 38.4 DAY 44 FOOTAGE DRILLED 116 NLTA LTH/YTD _~/_~ EST. DAY 45 SIZE OF LAST CSG 7.000 LTA LTH/YTO /_~ DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 895 UATER DEPTH '80 LAST BOP TEST ~/~/9~ LAST CSG TEST ~8/~/~ / BHR INSPECTION (CUM. ROT HAS) PP1 @ Kill SPEED 1050 @ 20 PP2 · KILL SPEED 1800 @ 40 SUMMARY OF OPERATIONS (SflOU HOURS FOR EACH OPERATION) : 5.50 ORIENT & SLIDE FROM 97~7' TO 9763' 18.50 ROTARY DRLG ,~/~1.25 DEG MOTOR FROM 9763' TO 9853' T I ME ~.HRS.). CUM. ROT. HAS ROTATING MUD MOTOR TRIPPING C &C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOUR /BOP/UH TESTING BOP /UH RUNNING CASING CEMENTING PICKUP/LAY DOUR DS INSPECT BHA RIG UP/TEAR OOUN UAIT ON UEATHER/MAT EVALUATION CORING OTHERS 278.75 18.50 5.50 JEPI ALASKA DAILY DRILLING REPORT RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFOR~ WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PROG. DEPTH 12170 PRESENT DEPTH 9921 FOOTAGE DRILLED 68 SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 WATER DEPTH 80 / _ PRESENT ACTIVITY: ROTARY DRLG. W/MOTOR SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.00 ROTARY DRLG. W 1.25 DEG. MOTOR TO 9857t 3.00 TOOH FOR BIT PAGE 1 OF 1 ELEVAT. KB TO MSL 116.0 DATE ~9/!~/9~ DIST. KB TO BHF 38.4 DAY 45 NLTA LTH/YTD ___/___ EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 896 LAST BOP TEST ~9_/__!~/9~ LAST CSG TEST ~8.8_~/9~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 950 ~ 20 . PP2 @ KILL SPEED 1550 ~- 40 2.50 BHA - L/D JARS~ MWD. & MOTOR - P/U STRAIGHT MOTOR & JARS - L/D ~.~_..___ BENT HWDP - CHECK MOTOR 3.00 TIH - FILL PIPE g 4800t & SHOE .50 WASH & REAM TO BOTTOM 14.00 ROTARY DRLG. W/STRAIGHT MOTOR FROM 9§57~ TO 9921~ NOTE; CIRC. COAL UP AT BOTTOMS UP AFTER TIH GOOD TRIP OUT & IN HOLE IADC DULL GRADE BIT #14 - 7-8-BT-A-F-1-LT&JD-TO&HR CONE LOCKED UP DUE TO JUNK DAMAGE ON SHIRTTAIL OF BIT T I M E CUM. ROT. HRS 293.75 ROTATING 15.00 MUD MOTOR TRIPPING 6.00 c & C REAMING .50 SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/UH TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DOIJN DS 2.50 INSPECT BHA RIG UP/TEAR DOiJN WAIT ON UEATHER/MAT EVALUATION CORING OTHERS SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF I RIG NAME PLATFORM "A"' FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ Rfl . PRESENT ACTIVITY: SHORT TRIP PROG. DEPTH PRESENT DEPTH FOOTAGE DRILLED 126 SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 WATER DEPTH 80 /GALLOWAY DR 12170 ELEVAT. KB TO MSL 116.0 DATE ~9/]~/9~ 10047 DIST. KB TO BHF 38.4 DAY 46 NLTA LTH/YTD / EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS'SINCE LAST LTA' 897 LAST BOP TEST ~9/1~/9~ .LAST CSG TEST ~8_/_~Z/9~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 960 @ 20 PP2 @ KILL SPEED 1540 @ 40 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 22.50 ROTARY DRILLED FROM 9921~_~:~0~47'. .50 CHECK FLOg AND PuMP DRY JOB. 1.00 RUNNING SHORT TRIPPING TO-LOG AT REPORT TIME. NOTE: TIGHT SPOT IN OPEN HOLE AT 8370~ .. T I M E__(._H R S.). ..... CUM. ROT. [IRS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOUN /BOP/IJH TESTING BOP /IJH RUNNING CASING CEMENTING PICKUP/LAY DOIJN DS INSPECT BHA RIG UP/TEAR DOUR gAIT ON UEATHER/MAT EVALUATION CORING OTHERS 316.25 22.50 1.00 .50 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF I RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM UELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: ROTARY DRILLING PROG. DEPTH PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 ~ATER DEPTH 80 /GALLOWAY DR 12170 ELEVAT. KB TO MSL 116.0 DATE 10056 DIST. KB TO BHF 38.4 DAY 47 9 NLTA LTH/YTD / EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA- 898 LAST BOP TEST 9~L~/9~ LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 140~ @ 20 PP2 @ KILL SPEED 2150 @ SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : 1.00 COHT. SHORT TRIP. 1.50 CIRC AND COND HOLE. CHEC~ FLOW AND PUMP DRY JOB. 3.50 POH UITH BIT #15. TIGHT SPOT AT 8367'. · 50 L/D BHA. 4.00 ~U~L__~__.(.~~N WITH DUAL PHA~ER~DT~6MS___~T~__LOGGING TOOLS. UNABLE TO WORK TOOLS PAST 8180~. POH WITH TOOLS. LOST TWO CENTRILIZERS OFF LOGGING TOOLS. RDWL. 2.50 ~Z~U__BHA AND SURFACE TEST MWD. 2.50 RIH WITH BHA. FILL DP AT 4800' AND AT SHOE. TEST MUD AT SHOE. 3.00 CUT AND SLIP 100' OF DRLG LINE. CHANGE OUT SAVER SUB. 2.00 NIH WITH BHA. UORKED THROUGH BRIDGES OR LEDGES__.~._.~8~S_.z.~ZS._~_AND 9732. 1.50 REAMED OPEN HOLE FROM 9871 TO 10047'. TIGHT HOLE AT 9871' AND 9907'. .50 CLEANED UP BOTTOM OF HOLE. 1.50 PERFORM MWD SURVEY AND ROTARY DRILL FROM.lO047' TO 10056~. CONTACTED BLAIR UANDSELL WITH AOGCC AND RECIEVED PERMISSION TO DELAY WEEKLY BOP TEST UNTIL AFTER LOGGING OR LINER JOB. NOTE: DURING REAM TO BOTTOM SAW RUBBER RETURNS FROM CENTRALIZERS. IADCC BIT GRADE BIT #15 - 8-8-RG-A_z~ZI_~-ER-PR T I ME ~HRS2 CUM. ROT. HRS 317.75 ROTATING 1.50 MUD MOTOR TRIPPING 9.00 C & C 1.50 REAMING 2.00 SURVEYS JET REPAIRS 3.00 FISHING NIP UP/DOUN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOUN DS INSPECT BHA 3.00 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 4.00 SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLENG FOREMAN: SELTZ R H PRESENT ACTIVITY: DRILLING PROG. DEPTH PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 WATER DEPTH 80 /GALLOWAY DR 12170 ELEVAT. KB TO MSL __.~1~ DATE ~9_.~Z/9~ 10153 DIST. KB TO BHF 38.~ DAY &8 97 NLTA LTH/YTD / EST. DAY ~5 LTA LTH/YTD _~/_~ DAYS +/- DAYS SINCE LAST LTA 899 LAST BOP TEST ~_~_~ LAST CSG TEST 98.8.~Z/9~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 1400 @ 20 PP2 @ KILL SPEED 2150 @ ~0 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 23.50 DRLG FROM 1~056' TO 1~53' .50 PLATFORM-POWER FAILURE ' NOTE; GAS ALARM SOUNDED @ 0100 HRS - CAMP POWER WAS DUMPED DUE TO KATO GENERATOR CAT MOTOR OVER HEATED. ALL PERSONNEL RESPONDED NO~; WILL RUN SPERRY SUN LOGGING TOOL AFTER BIT RUN #16. T I ME _~_H_R_S2 ....... CUM. ROT. HRS ROTAT I NG MUD MOTOR TRIPPING I C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /80P/UH TESTING BOP /UH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOUN WAIT ON UEATHER/MAT EVALUATION CORING OTHERS 341.25 23.50 .5O SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" UELL A41A-11 UORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: PREPARE TO POH PROG. DEPTH PRESENT DEPTH FOOTAGE DRILLED 102 SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 UATER DEPTH 80 /GALLOUAY DR 12170 ELEVAT. KB TO MSL 116.0 DATE ~/~/~ 10255 DIST. KB TO BHF 38.4 DAY 49 NLTA LTH/YTD / EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 900 LAST BOP TEST ~9/1]/9~ LAST CSG TEST ~8_~gZ/9~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 1150 @ 20 PP2 @ KILL SPEED 1800 @ 40 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 23.50 ROTARY DRILL FROM 10153' TO 10255' .50 PERFORM MWD_~UR~V~Y.CHE~E F__L~W.. AND PUMP DRY JOB. PREPARING TO POH TO RUN DRILL PIPE CONVEYED LOGS AT REPORT TIME. T I M E_.(,.HRS.)._ CUM. ROT. HRS 364.75 ROTATING 23.50 MUD MOTOR TRIPPING C & C REAMING SURVEYS .50 JET REPAI RS FISHING NIP UP/DO~N /BOP/UH TESTING BOP /tJH RUNNING CASING CEMENTING PICKUP/LAY DOUN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON UEATHER/MAT EVALUATION CORING OTHERS SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM #A" WELL A41A-11 WORK ORDER 739930 SIOE TRACK DRILLING FOREMAN: SELTZ R H PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE ~L~/9~ PRESENT DEPTH 10255 DIST. KB TO BHF 38.4 DAY 50 FOOTAGE DRILLED NLTA LTH/YTD / EST. DAY 45 SIZE OF LAST CSG 7.000 LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 901 UATER DEPTH 80 LAST BOP TEST ~9/~/9~ LAST CSG TEST ~8/~/9~ /GALLOUAY DR BHA INSPECTION (CUM. ROT HMS) PRESENT ACTIVITY: POH WITH DP CONVEYED LOGS SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 3.00 POH WITH BHA AND BIT #16. 1.00 _L/D BHA. 1.0~0 ~/~U_SPERRY SUN LOGGING TOOL BHA. PP1 @ KILL SPEED PP2 @ KILL SPEED 5.0________~0 RIH WITH DRILL PIPE CONVEYED LOGGING TOOLS. FILL DP AT 4200' AND SHOE. SEVERAL TIGHT SPOTS IN OPEN HOLE ON WAY TO BOTTOM WITH TOOLS. .50 BEGAN LOGGING DOWN AT 10144~ TO 10255~ .(~.0). LOGGED UP FROM 10255~ (TD) TO 7480' WITH SPERRY SUN DP CONVEYED MEMORY LOGGING TOOL. TIGHT SPOT AT 8796~. 8_.:.. s__o 1.0...____.~0 MADE RIPER TRIP TO BOTTOM - NO TIGHT SPOTS IN OPEN HOLE. 2.00 CIRC AND COND MUD. CHECK FLOW AND PUMP DRY JOB. 2.00 BEGIN TO POH WITH LOGGING TOOLS. IADC BIT GRADE #16 - 4-5-BT-M-F#2-I-ER-LOG 100~ @ 20 1550 @ 40 TIME l~ CUM. ROT. HRS 364.75 ROTATING MUD MOTOR TRIPPING 11.00 C & C 2.00 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DO~N DS INSPECT BHA 2.00 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 9.00 JUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM UELL A41A-11 UORK ORDER 739930 PROG. DEPTH 12170 PRESENT DEPTH 10295 FOOTAGE DRILLED 40 SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 SIDE TRACK UATER DEPTH 80 DRILLING FOREMAN: SELTZ R H /GALLOUAY DR PRESENT ACTIVITY: ROTARY[SLIDE DRILLING SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.50 CONT TO POH WITH LOGGING TOOL. 1.00 ~/D BHA WITH LOGGING TOOL. ELEVAT. KB TO MSL 116.0 DATE ~9/~/9~ DIST. KB TO BHF 38.4 DAY 51 NLTA LTH/YTD ___/___ EST. DAY ..~ LTA LTH/YTD ___/___ DAYS +/- DAYS SINCE LAST LTA 902 LAST BOP TEST 9~/ZE/9~ LAST CSG TEST ~8/~/9~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 175~ @ 30 PP2 @ KILL SPEED 2600 @ 50 3.50 LOU GRAMALDI UITH AOGCC ON PLATFORM TO UITNESS BOP TEST. PERFORMED WEEKLY BOP TESTS. 2.00 WORK ON TOP DRIVE AND SERVICE RIG. 2.00 ~/~;BHA WITH BIT #18. ORIENT MOTOR AND CHECK MUD. 4.50 NIH UITH BHA. FILL DP AT 4200~ AND CASING SHOE. 1.50 ROTARY DRILL FROM 10255~ TO 10260~. 8.00 ROTARY DRILL [ SLIDE FORM 10260' TO 10295' DRILLING AHEAD AT REPORT TIME. NOTE: OPEN HOLE LOGS SHOUED US TO BE IN THE UEST FORLANDS. UE UILL BE MAKING 1 TO 2 MORE BIT RUNS TO TURN THE HOLE TO THE LEFT BEFORE SETTING PIPE. NOTE: HIGH DAILY COSTS INCLUDE SUS CHARGE~:OE:~Z3,00~_FOR UNSUCCESSFUL LOGGING ATTEMPT ~Q:~27.~00 FOR SPERRY-SUN LOGGING RUN. CUM. ROT. HRS 374.25 ROTATING 1 .50 MUD MOTOR 8.00 TRIPPING 5.50 C & C REAMING SURVEYS JET REPAIRS 2.50 FISHING NIP UP/DOUN /BOP/UH TESTING BOP /UH 3.50 RUNNING CASING CEMENTING PICKUP/LAY DOUR DS INSPECT BHA 3.00 RIG UP/TEAR DOUR WAIT ON UEATHER/MAT EVALUATION CORING OTHERS SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" UELL A41A-11 UORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SElTZ R H PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE PRESENT DEPTH 10427 DIST. KB TO BHF 38.4 DAY 52 FOOTAGE DRILLED 132 NLTA LTH/YTD / EST. DAY 45 SIZE OF LAST CSG 7.000 LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 903 WATER DEPTH 80 LAST BOP TEST ~9/~ LAST CSG TEST /GALLOWAY DR BHA INSPECTION (CUM. ROT HRS) PRESENT ACTIVITY': ROTARY/SLIDE DRILLING SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : 24.00 ROTARY/SLIDE DRILLING FROM 10295~ TO 10427~. PP1 @ KILL SPEED PP2 ~ KILL SPEED 1250 @ 20 1950 @ 40 T I M E_.(.H~R S_2 ....... CUM. ROT. HRS 398.25 ROTATING 11.00 MUD MOTOR 13.00 TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOUN /BOP/UH TESTING BOP /UH RUNNING CASING CEMENTING PICKUP/LAY DOUR DS INSPECT BHA RIG UP/TEAR DOUN UAIT ON UEATHER/MAT EVALUATION CORING OTHERS SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM UELL A41A-11 WORK ORDER 739930 SIDE TRACK ; DRILLING FOREMAN: WELLS R V PROG. DEPTH 12170 PRESENT DEPTH 10457 FOOTAGE DRILLED 30 SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 UATER DEPTH 80 /GALLOWAY DR PRESENT ACTIVITY: ROTARy/SLIDE DRILLING SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : 3.50 ~OT~R__Y ~ SLIDE DRILL FROM 10427 TO 10442~ 4.50 ~[=EL~U~.=~UMP DRY JOB AND POH UITH BHA. 1.___~5~ [/D BHA AND ~/U NEU BHA UITH BIT #1~. 4.00 NIH UITH BNA. FILL DP AT 4200~ AND CASING SHOE. ELEVAT. KB TO MSL 116.0 DATE ~9_Z~Z/9~ DIST. KB TO BHF 38.4 DAY S3 NLTA LTN/YTD / EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST ETA' 904 LAST BOP TEST ~9_Z:~ LAST CSG TEST ~~ BNA INSPECT ON (CUM. ROT HRS) PP1 @ KILL ~PEED 130~ @ 20 PP2 @ KILL SPEED 1975 @ 40 2.00 CUT AND SLIP 100~ DRILL LINE. INSPECT BRAKE ASSEMBLY ON DRAW UORKS AND SERVICE RIG. 1.50 RIH UITH BHA. REAM THRU LEDGE AT 9895'. 1.50 BREAK CIRCULATION AT 10371~ AND ATTEMPT TO REAM TO BOTTOM. PACKED OFF UITH HIGH TORQUE - PULLED FREE AND REAMED TO BOTTOM. 1.50 ROTARY DRILL FROM 10442' TO 10446~. 4.00 ROTARY/SLIDE DRILL FROM 10446' TO 10457~. DRILLING AHEAD AT REPORT TIME. IADC DULL BIT GRADING #18 - 2-3-NO-A-E-I-ER/PR TIME .~1 ....... CUM. ROT. HRS 406.25 ROTATING 3.00 MUD MOTOR 5.00 TRIPPING 10.00 C & C .50 REAMING 1.50 SURVEYS .50 JET REPAIRS FISHING NIP UP/DOWN /BOP/WN TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA 1.50 RIG UP/TEAR DOUN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 2.00 SUEPI ALASKA DAILY DRILLING REPORT PAGE I OF 1 RIG NAME PLATFORM aA" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM #A" UELL A41A-11 UORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: WELLS R V PRESENT ~CTIVITY: ROTARY/MOTOR DRILLING PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE ~Z~/9~ PRESENT DEPTH 10554 DIST. KB TO BHF 38.4 DAY ._~5~ FOOTAGE DRILLED 97 NLTA LTH/YTD / EST. DAY __4~ SIZE OF LAST CSG 7.000 LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 905 WATER DEPTH 80 LAST BOP TEST ~9/~/9~ LAST CSG TEST ~8/~/9~ /GALLOUAY DR BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 1300 @ 20 PP2 @ KILL SPEED 1975 @ 40 SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : 24.00 ~OTA~MOTOR DRILL FROM 10457~ TO 10554~. PREPARING TO SURVEY AT REPORT TIME. NOTE: PUMPED HIGH VIS SWEEP AT 10457~ TO HELP CLEANUP HOLE AND PREVENT PACK-OF[/STICKING PROBLEMS ENCOUNTERED YESTERDAY. I_ = ~_T.TX_.M_.E__:UR_~S.Z ........ CUM. ROT. HRS 430.25 ROTATING 8.00 MUD MOTOR '16. O0 TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOUR /BOP/UH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BNA RIG UP/TEAR DOUN UAIT ON IJEATHER/MAT EVALUATION CORING OTHERS SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG MANE PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" UELL A41A-11 UORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: UELLS R V PRESENT ACTIVITY: ~fU BHA PROG. DEPTH 12170 PRESENT DEPTH 10616 FOOTAGE DRILLED 62 SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 UATER DEPTH 80 /GALLOWAY DR SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : ELEVAT. KB TO MSL 116.0 DATE ~_~/_~_~ DIST. KB TO BHF 38.4 DAY 55 NLTA LTH/YTD ___/___ EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 906 LAST BOP TEST g~/~/~ LAST CSG TEST g~gZ/~ BHA INSPECTION (CUM. ROT HRS) PP1 a KILL SPEED 1300 @ 20 PP2 @ KILL SPEED 1975 @ 40 17.50 ROTARY/MOTOR_p_~R~LL~EOM_~O_,.~S4~'~O~)~616'. MOTOR STALLED OUT AT 10616~. UNABLE TO DRILL DEEPER. .50 CHECK FLOW AND PUMP DRY JOB. 3.50 POH ~ITH BHA. 2.50 L/O_BHA. L/p 7 JTS BENT HWDP. CHECK ORIENTATION OF MOTOR. MOTOR ORIENTATION OFF 90 DEGREES. MAKING UP MEg BHA UITH BIT #20 AT REPORT TIME. DULL BIT GRADING BIT #19 - 6-8-BT-A-F-I-CT-HR TIME_~RS~__ CUM. ROT. HAS 447.75 ROTATING 7.00 MUD MOTOR 10.50 TRIPPING 3.50 C & C .50 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/UH TESTING BOP /UH RUNNING CASING CEMENTING PICKUP/LAY DOUN DS INSPECT BHA 2.50 RIG UP/TEAR DOWN gAIT ON UEATHER/MAT EVALUATION CORING OTHERS SWEPI ALASKA DALLY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A# FIELD MIDDLE GROUND SHOAL LEASE PLATFORM #A# WELL A41A-11 UORK OROER 739930 SIDE TRACK DRILLING FOREMAN: UELL~ R V PROG. DEPTH 12170 PRESENT DEPTH 10681 FOOTAGE DRILLED 65 SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 ~ATER DEPTH 80 /GALLOgAY DR ELEVAT. KB TO MSL 116.0 DATE ~9__/_.~/_~ DIST. KB TO BHF 38.4 DAY 56 NLTA LTH/YTD / EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 907 LAST BOP TEST ~9/~E/9~ LAST CSG TEST g8/~/9~ BHA INSPECTION (CUM. ROT HRS) PRESENT ACTIVITY: ~OTART/MOTOR DRILLING SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : .50 COMPLETE_M/U OF BHA. SURFACE TEST MUD. TEST FAILED. 1.00 POH UITH MWD AND CLEAN. REINSTALL AND SURFACE TEST. TEST OK. 4.00 RIH UITH BHA. FILL DP AT 4200 AND CSG SHOE. .50 RUN THROUGH OPEN HOLE TO BOTTOM. TIGHT SPOT AT 8800'. .50 REAM OPEN HOLE FROM 10527 - 10616~. 17.50 ROTARY/MOTOR DRILL FROM 10616~ TO 10681~ NOTE TO AlT PARTNERS - MANHOURS FOR OCTOBER ARE DUE! PLEASE RETURN TO LARRY LITTLE. THANKS TO SWS - ALLREADY HAVE RECIEVED YOURS. PPl @ KILL SPEED PP2 g KILL SPEED 1080 @ 20 1800 @ 40 T I M E .(._HAS)_ ..... CUM. ROT. HRS 465.25 ROTATING 10.50 MUD MOTOR 7.00 TRIPPING 4.50 C & C REAMING .50 SURVEYS 1.00 JET REPAIRS FISHING NiP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA .50 RIG UP/TEAR DOUN WAIT ON UEATHER/MAT EVALUATION CORING OTHERS SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" UELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: UELLS R V PRESENT ACTIVITY: ROTARY DRILLING PROG-. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE !gZg!~l PRESENT DEPTH 10712 DIST. KB TO BHF 38.4 DAY ._~5z FOOTAGE DRILLED 31 NLTA LTH/YTD ___/___ EST. DAY __~4~ SIZE OF LAST CSG 7.000 LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 908 UATER DEPTH 80 LAST BOP TEST ~9/'~E/'9~ LAST CSG TEST 98/~,/9~ /GALLOWAY DR BHA INSPECTION (CUM. ROT HRS) PPl @ KILL SPEED 1100 ~ 20 PP2 @ KILL SPEED 1850 @ 40 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH' OPERATION) : 4.00 ROTARY/MOTOR DRILLING FROM 10681 TO 10691'. .50 CHECK FLOW AND PUMP DRY JOB. 4.00 POH 14ITH BHA. 1.00 ~ BHA AND MZU BHA UITH BIT #21. 4.50 R-IH WITH BHA. FILL DP AT 4200' AND CASING SHOE. RIH TO 1~.400' 2.00 BREAK CIRCULATION AND REAM OPEN HOLE FROM 10,400' TO 10~691'. 8.00 ROTARY DRILL FROM 10691' TO 10712'. IADC DULL BIT GRADING #20 - 4-8-BT-GM-E-3/8-RG-PR TIME CUM. ROT. HRS 477.25 ROTATING 12.00 MUD MOTOR TRIPPING 8.50 C & C .50 REAMING 2.00 SURVEYS JET REPAIRS FISHING NIP UP/DOUR /BOP/UH TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DOUR DS INSPECT BHA 1.00 RIG UP/TEAR DOUR gAIT ON UEATHER/MAT EVALUATION CORING OTHERS SUEPI ALASKA DALLY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" UELL A41A-11 UORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: UELLS R V PRESENT ACTIVITY: ~/U TO RUN CASING PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE !~g~ PRESENT DEPTH 10743 DIST. KB TO BHF 38.4 DAY 58 FOOTAGE DRILLED 31 NLTA LTH/YTD / EST. DAY 45 SIZE OF LAST CSG 7.000 LTA LTH/YTD / DAYS +/- DEP. Of LAST CSG 7765 DAYS SINCE LAST ETA 909 WATER DEPTH 80 LAST BOP TEST g9/Z~/9~ LAST CSG TEST ~Z~Z/-~ /GALLOWAY DR BHA INSPECTION (CUM. ROT HRS) PPi @ KILL SPEED 1100 @ 20 PP2 @ KILL SPEED 1850 @ 40 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 10.00 ROTARY DRILL FROM 10712~ TO 10743~. 2.00 CHECK FL~OW,, PUMP PI~, AND RUN SHORT TRIP. TIGHT SPOT AT 10466 AND 8650' 1.00 SERVICE TOP DRIVE AND RIG. 1.50 MAKE GOOD SHORT TRIP - NO BAD SPOTS. 3.50 CIRCULATE UEIGHTED PILL (50 BBLS - 15#~. CONDITIONED HOLE. 4.50 CHECK FLO~._~UM~ DRY JOB. AND POH UITH BHA. DROPPED DRIFT WHEN UP IN CASING SHOE. 1.00 L_JD BHA. .50 PREP TO RUN CASING. NOTE: BLAIR UANDZELL OF AOGCC DECLINED UITNESS OF BOP TEST AND GAVE PERMISSION TO RUN TEST AFTER LINER JOB. \ T I ME [~RS1 ....... CUM. ROT. HRS 487.25 ROTATING 10.00 MUD MOTOR TRIPPING 8.00 C & C 3.50 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOUR /BOP/UH TESTING BOP /UH RUNNING CASING CEMENTING PICKUP/LAY DOUN DS INSPECT BHA 1.00 RIG UP/TEAR DOUR ~AIT ON UEATHER/MAT EVALUATION CORING OTHERS 1.50 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM WELL A41A-11 WORK ORDER 739930 SIOE TRACK DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: PROG. DEPTH 1_~2~Z~ ELEVAT. KB TO MSL _~1~.C) DATE ~0/'~/9~ PRESENT DEPTH 1.~OZ~~ DIST. KB TO BHF 38.4 DAY 59 FOOTAGE DRILLED NLTA LTH/YTD / EST. DAY 45 SIZE OF LAST CSG 7.000 LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 910 WATER DEPTH 80 LAST BOP TEST ~9_~/~ LAST CSG TEST ~L~Z/~ BHA INSPECTION (CUM. ROT HAS) PP1 @ KILL SPEED PP2 ~ KILL SPEED /GALLOWAY DR SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 11.00 RIG AND RAN 123 ~TSz~5060' TOTAL PIPE~ 5" 18# P-ilO STL CSG TO 7" SHOE 2.00 CIRC 1 DP VOL AT 900.PS~..5 BBL MIN. ~HANGER SETS AT 1300 PSI~ 2.50 FINISHED RUN C~_]L~TTO_.~M~ 10743'. DETAIL: ENERPRO SHOE AT 10743__~.~____ BAKER FLOAT COLLAR AT 10~97.~__BAKER LANDING COLLAR AT 10655'. RAN 123 TOTAL JTS~ 5060~ OF CSG. BAKER "HMC" LINER HAN~.~_.6__~ TIE BACK SLEEVE TOP AT 5663~. PICKED UP CEMENTING HEAD. TIME (MRSZ CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING Ic&c SURVEYS JET REPAIRS 2.50 DROP BALL TO SET HANGE~. CIRC BALL DOWN AT 1500 ~SI.c_~_2 ~L/~IN RATE. BALL LANDED IN SEAT~ PRESSURE UP T/~200 PSI AND SHEARED OUT SEAT. BEGAN CIRC AT 2.SB~LMIN A~_9~O~ 3.00 HELD PRE JOB SAFETY/PROCEDURES MEETI~G_~._~OT. A NEW GAME PLAN TOGETHER. HO~CO PUMPED 20 BBLS oLL,__~O BBLS WATER .~/SURFB~AN~L_!~B~LS(56~O_~X_) I FISHING @ 20 @ 40 487.25 3.00 4.50 13.50 3.00 TRINITY LITE CEMEN~_Y.__EILD 1.32 WT. 13.2 }.=~40% HR-5 USING BATCH MIXERS. BAKER DROPPED DAR_._~T~ HOW._____~CO~DIS__~PLBCE~_ ~/.~_BBLS WATER__~SURFACTANT~__5__.~B~LS_~IL~_~8 BBLS 9.2 PPGHUO~._~2§_B_~eL__ 15 PPG PILL FOLLOWED BY 17 BBLS OF 12.2 PPG MUD. DID NOT BUMP PLUG. CIP AT 0309 NAS 10~Z95. BLED OFF P~._~LOATS HELD. 3.0~ LAY DOWN CEMENTING NEA~, ~O~L~Y DOWN C-2 RUNNING TOOL.__ NOTE: AFTER LOSING CIRC WE NEVER REGAINED RETURNS. PUMPED JOB WITHOUT RETURNS BUT HAD A STEA~Y,_.~CONT._~I~OUS PRESSURE RISE AFTER CEMENT CAME AROUND THE SHOE ..... HOLE STOOD STATIC DURING THE JOB EXCEPT FOR VERY SMALL ATTEMPT AT RETURNS DURING LAST 5 BBLS OF JOB. _ NiP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM WELL A41A- 11 SJORK ORDER 739930 SIDE TRACK ~-..~ _ DRILLING FOREMAN: WELLS R V PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE PRESENT DEPTH 10743 DIST. KB TO BHF 38.4 DAY 60 FOOTAGE DRILLED NLTA LTH/YTD / EST. DAY 45 SIZE OF LAST CSG 7.000 ETA LTH/YTD / DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST ETA 911 WATER DEPTH 80 LAST BOP TEST !O__/_~E/_~ LAST CSG TEST / BHA INSPECTION (CUM. ROT HRS) PRESENT ACTIVITY: WEEKLY BOPE TESTS PP1 @ KILL SPEED PP2 @ KILL SPEED SUMMARY OF OPERATIONS (SHO~ HOURS FOR EACH OPERATION) : 5.00 LAY DOWN EXTRA D~/HW~/D~S OUT OF DERRICK. 2.50 MU BIT AND TIH 1.50 CUT DRILLING L I~N~ SERVICE RIG_jFTOP DRIVE. 1.00 FINISH TIH T_.,/TOP OF LINER AT 5663~ NO CEMENT ANYWHERE. 2.00 CIRC COND MUD TO BALANCE OUT MULTIPLE MUD WE~GHT~ FINAL IS 11.4 PPG. .50 TEST LINER ~P, PLIM~NG FLUID AWAY AT 580 PSI. 13.4 PPG EMW AT THE LINER TOP. 13.2 PPG AT THE OLD GAS WELL PERFS. 2.50 POH..__~CLEANOUT ASSMY. 4.50 MAKE UP LINER TOP ISOLATION PACKER_.~._~H VERY SLOWLY. 1.00 MAKE UP TOP DRIVE. SET ISOLATION PACKER IN 5" LINER..__~TIE=EA_~.C[~._~S[Z_~2~- DOWN WEIGNT.~.~._.~ROT..~.AT._E 10 TURNS TO THE RIGHT TO RELEASE. PICKED UP 12~ SET BACK DOWN 2~ AND ENGAGED PACKER TIE BACK SLEEVE CONFIRMING IT SET AND WE ~ERE ABOVE IT ~ITH RUNNING TOOL. SET 60K DOWN WEIGHT ON PACKER TO ENERGIZE ELEMENT. PICKED UP 15~L_CLOSED RAMS PRESSURED UP T__/900 PSi PUMPING FLUID AWAY. RELEASED PRESSURe. BLED DOWN T~/525 PSi. BLED OFF OPENED _RAM.__~S~ S__ET 6OK DO~N WEIGHT ON PA~_KER~LO~D.__~R~M._.~S~_~RESSURED UP T_/_~_~QO PSI AT ( BBLS MIN RAni: PUMPED ~_~B~ S~UT D~W~_~U~:~S~g~[ BLED DOWN T[~ PS~. BLED OFF PRESSURE. NO GOOD TEST. z.oo POH ~/~-2 RUNN]NG._[~L.~AY~O~N TOOLS. 1.50 DOING ~EEKLY BOPE TEST ~HILE ~OBLIZING 5" AND 7" RTT~JCHAMP PACKERS. a 2O @ 4O TIME ~1. CUM. ROT. HRS 487.25 ROTATING MUD MOTOR TRIPPING 12.50 C & C 2.00 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /UN 1.50 RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 5.00 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 3.00 lYEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" PROG. DEPTH FIELD MIDDLE GROUND SHOAL PRESENT DEPTH 10743 LEASE PLATFORM "A" FOOTAGE DRILLED YELL A41A-11 SIZE OF LAST CSG 7.000 YORK ORDER 739930 DEP. OF LAST CSG 7765 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: WELLS R V ........ / PRESENT ACTIVITY: PICKING UP 2 Z/8" AOH DRILL PIPE SUMMARY OF OPERATIONS (SHOY HOURS FOR EACH OPERATION) : 4.00 FINISHED WEEKLY BOPE TEST. ELEVAT. KB TO NSL 116.0 DATE DIST. KB TO BfiF 38.4 DAY 61 NLTA LTH/YTD / EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 912 LAST BOP TEST !0/~/9~ LAST CSG TEST ~8/~/9~ BHA INSPECTION (CUM. ROT HAS) PP1 g KILL SPEED @ 20 PP2 @ KILL SPEED a 40 9.00 PICKED UP 12 EACH 4 ~/4" DC~..~S~__36 JTS 3 1/2" fiWDP AND Tlfi [L!OL:. 5654' .50 STING INTO ISOLATION PACKER'S TIE-BACK SLEEVE ~L~EAL__ASSNY AND NO-GO. ~ET 70 K DOUN:UE~GHT, SAW PINS SHEAR AT 4OK. PRESSURED UP INSIDE TO ~O_~~O~__~TUNG P~SSURED UP_6NUL~ [/2500 PSI, O~K_~FLIO HIMS. 3.50 ~UMP PILL, POH. LAYED DOWN 12 DC'S AND 36 H~DP. 7.00 REARRANGE 3 1/2" DP IN DERRICK AND PICKING UP Z ~/8" DRILL STRING. T I M E [_.HR_S2 CUM. ROT. HRS 487.25 ROTATING MUD MOTOR TRIPPING 10.00 C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH 4.00 TESTING BOP /WH .50 RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 9.50 INSPECT BHA RIG UP/TEAR DOUN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS SWEPI ALASKA DALLY DRILLING REPORT PAGE I OF I RIG NAME PLATFORM #A# FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A41A-11 WORK ORDER ?~99~0 SIDE TRACK DRILLING.FOREMAN: ~ELLS R V PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE ~ PRESENT DEPTH DIST. KB TO BfiF 38.4 DAY 62 FOOTAGE DRILLED NLTA LTH/YTD ~ /__ EST. DAY 45 SIZE OF LAST CSG 7.000 LTA LTH/YTD / .... DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 913 WATER DEPTH 80 LAST BOP TEST ~ LAST CSG TEST ~0/04/95 / BHA INSPECTION (CUM. ROT fiRS) PRESENT ACTIVITY: DRLG CMT IN 5' LINER PP1 a KILL SPEED ~50 a 20 PP2 a KILL SPEED a 40 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : ~.00 P/U AND DRIFT'2 ?/8# DRILL PIPE 3.00' RIM ~/ 3_11/2" DRILL'PIPE.(SLM). 4.00 TAG GREEN CEMENT AT lO,184~.UASfi REAM TO lO,274[fFIRM CEMENT).DRILL CEMENT F/lO~4~ TO lO,29Z~.CEMENT WAS DRILLING AT 5'/HR. ~.00 -CHECK F/ FLO~,PUMP DRY JOB,POH FOR BIT.MILL UAS JAMMED WITH RUBBER AND 'ALUMINUM~ 4.00 MAKE UP ( 1/8~. BIT AND RIH g/4 1/8".~IT. 2.00 DRLG CEMENT FROM 10,292 SHOE AT IO,7~'-FLT COLLAR A[~,697'-LANDING COLLAg ~ 1~,655' BUiLDiNG NEU VOLUME ~fiILE ORILLZNG CEMENT J TIME J CUM. ROT. fiRS J ROTATING J MUD MOTOR J TRIPPING Ic&c J REAMING J SURVEYS J JET J REPAIRS I FISfiiNG J NIP UP/DOWN /BOP/WH I TESTING BOP /NH I RUNNING CASING J CEMENTING J PiCKUP/LAY DO~N DS J INSPECT BHA J RIG UP/TEAR J ~AIT ON WEATHER/MAT J EVALUATION J CORING J OTfiERS 493.25 6.00 ~8.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM #A# FIELD MIDDLE GROUND SHOAL LEASE PLATFORM UELL A41A-11 WORK ORDER 739930 SIDE TRACK ORILLING FOREMAN: YELLS R V PRESENT ACTIVITY: POH CET LOG SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 6.50 DRLG CEMENT IN'5M LINER F/10~292t T0_~0~6~5~. .50 TEST CASING TO 2500 PSI.OK. PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE ~0/07/9~ PRESENT DEPTH 10749 DIST. KB TO BHF 38.4 DAY 63 FOOTAGE DRILLED 6 NLTA LTH/YTD . / EST. DAY 45 SIZE OF LAST CSG 7.000 LTA LTH/YTD __/__ DAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 914 rATER DEPTH 80 LAST BOP TEST ~ LAST CSG TEST 10/06/95 / BfiA INSPECTION (CUM. ROT fiRS) PP1 g KILL SPEED 110.___~0 a 30 PPI g KILL SPEED g 40 4.50 DRLG CEMENT F/10t~45t TO IO,7~9t.DRILLED LANDING COLLAR,FLT'COLLAR, SHOE AND 3tFORMATION. _1.00 CIRC..BOTTOMS UP. .50 DO E~M TEST-TO 12.5 PPG,OK. 3.00 DISPLACE UELL ~ITH 8.5 PPG NE~ OIL BASE MUD. .4.0~ POH AND BREAK BIT - 4.00 ~/U RUN CET LOG ON 5" LINER.. TIME CUM. ROT. HAS ROTATING MUD MOTOR TRIPPING 4.00 c&c 4.00 REAMING SURVEYS JET REPAIRS FISHING NiP UP/DOUN /BOP/~H TESTING BOP /VH RUNNING CASING CEMENTING PICKUP/LAY DOUN DS INSPECT BHA RIG UP/TEAR DOWN UAIT ON UEATHER/MAT EVALUATION 4.00 CORING OTHERS 1.00 504.25 11.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1'OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM ~ELL A41A-11 ~ORK ORDER 739930 SiDE TRACK DRILLING FoRE'AN: YELLS R V PRESENT ACTIVITY: ~IH U/BIT # 24 SUMMARY OF OPERATIONS (SHOW NOUNS FOR EACH OPERATION) : 1.0_.__~0 F~NISX POH ~/CET LOG AND RIG DOWN SCHLUMBERGER. 8.50 MAKE UP BIT ANO BHA, SURFACE CHECK MUO AND RIX. 1.00 ROTARY DR~LL F/I0,749 TO 10A7~1 ~/ ~IT # 23. 5.00 ORIENT AND SLIDE F/10~771 TO 10~831. .50 M~D SURVEY~X~C~ F/FLOW AND PUMP DRY JOB. 4.00 POH ~/BIT. .50 REPLACE ~EAR BUSHING.~OLD ONE ~ORE OUT). _3.50 MAKE UP BIT # 2~,SURFACE CHECK M~D AND RIH. PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE J0/08/9~ PRESENT DEPTH 10831 DIST. KB TO BHF 38.4 DAY 64 FOOTAGE DRILLED 82 NLTA LTN/YTD __/__ EST. DAY 45 SIZE OF LAST CSG 7.000 LTA LTH/YTD . ./~ OAYS +/- DEP. OF LAST CSG 7765 DAYS SINCE LAST LTA 915 WATER OEPTH 80 LAST BOP TEST 10/04/95 LAST CSG TEST !0/06/95 / BfiA INSPECTION (CUM. ROT HMS) PP1 g KILL SPEED 900 g 20 PP2 g KILL SPEED 1550 g 30 TIME (HAS)' CUM. ROT. HMS ROTATING 1.00 MUD MOTOR 5.00 TRIPPING 15.50 C & C REAMING SURVEYS .50 JET REPAIRS FISHING NiP UP/DO~N /BOP/~H TESTING BOP /UH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOUN VA[T ON ~EATHER/MAT EVALUATION CORING OTHERS 2.00 510.25 SUEPI ALASKA DAILY DRILLING REPOR1 PAGE 1 OF 1 RIG NAME PLATFORM #A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" UELL A41A-11 UORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: UELLS R V PRESENT ACTIVITY: DRLG ~/ BIT # 25 PROG. DEPTH PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 UATER DEPTH 80 12170 ELEVAT. KB TO HSL 10942 DIST. KB TO BHF 111 NLTA LTH/YTD 116.0 D A T E 38.4 DAY ...~6~ ___/___ EST. DAY 45 LTA LTH/YTD ___/___ DAYS +/- DAYS SINCE LAST LTA 916 LAST SOP TEST lo/gE~A LAST CSG TEST lO_.Zg~/~A BHA I.SPECTIO. CCUM. ROT HMS) PP1 @ KILL SPEED 1075 @ 20 PP2 @ KILL SPEED 2475 a 30 SUMMARY OF OPERATIONS (SHO~ HOURS FOR EACH OPERATION) : 1.50 ~!~_~/ B!~:~=24.~II.L PIP__._._[E AT 5648' AND CHECK MOTOR.STOP AT SHOE. 1.00 CUT DRLG LINE. 1.00 INSPECT BRAKE BLOCKS AND TIGXTEN BOLTS.SERVICE RIG. .50 REAM FROM 10811~T0 10831~. 2.50 ROTARY DRILL F/10831~T0 10837~. 1.00 ORIENT AND SLIDE F/10867~T0 10892~. 2.00 ROTARY DRILL F/10892~T0 10913~. 1.00 MOTOR STALLED BACK REAM THRU' TIGXT HOLE [/10913'T0 lO~O?,. 3.50 ~=~U~E~.CHECK FOR FLOg,PUMP DRY JOB,PON FOR BIT. 2.00 CHANGE BIT AMD INSTALL JET IN MOTOR.ORIENT MOTOR AND MUD. 4.50 RIH. FILL PIPE AT 5620~ AND CHECK MUD.RIH 1.00 TAGGED AT 10831~.REAM F/10831/T0 10913'. ~.50 ROTARY DRILL F/10913~T0 10917~.ORIENT AND SLIDE F/10917~T0 10942~. PUMP HI-ViS S~EEP. T ! M E CUM. ROT. HMS ROTAT I NG MUD MOTOR TRIPPING Ic&c I REAMING SURVEYS JET REPAIRS FISHING NIP UP/DO~JN /BOP/UN TESTING BOP RUNNING CASIWG CEMENTING PICkUP/LAY DOUN DS INSPECT BHA RIG UP/TEAR DOUN UAIT ON UEATHER/MAT EVALUATION CORING OTHERS 518.25 4.50 3.50 9.50 4.00 SUEPI ALASKA DAILY DRILLING REPORT PAGE I OF 1 RIG NAME PLATFORM "A# FIELD MIDDLE GROUND SHOAL LEASE PLATFORM UELL A41A-11 UORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: ~ELLS R V PRESENT ACTIVITY: POH ,~_.~ BIT # 26 PROG. DEPTH PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 7.000 OEP. OF LAST CSG 7765 UATER DEPTH 80 12170 ELEVAT. KB TO MSL 116.0 DATE !o/!9/~ 11066 DIST. KB TO BXF 38.4 DAY 124 ALTA LTX/YTD /___ EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 917 LAST BOP TEST !0_~/9~ LAST CSG TEST !0/~/9~ BHA INSPECTION (CUM. ROT HMS) PP1 g KILL SPEED 102b @ 20 PP2 @ KILL SPEED 2720 @ 30 SUMMARY OF OPERATIONS <SHOU HOURS FOR EACH OPERATION) : 3.00 DRLG ~/ BIT ~=2~.~3 M____.~OTOR_~S~S~,~L[DE [/109~:TO:!O~70.ROTARY DRILL F/10970 TO 10982.SURVEY. 4.00 ~EC~ F/[LOH. POH_._.T._~O_~HC)E.~UHP_~RY Jp~,FINIS~ POX F! BIT. 1.50 CHANGE B[~DJU~T ~gT..gE_T9 _1.IS:BEND.ORIENT MOTOR AND M~D AND SURFACE CHECK MUD. 3.50 RIX ~/~BIT ~:26,[[[L_P__]~E AT~5620 AND SHOE. .50 REAM F/10832 TO 10982. 7.50 ROTARY DRILL F/10982 TO 10985.SLIDE F/10985 TO 11014.ROTARY DRILL F/11014 TO 11038.SLIDE [/~1038 TO 11051.ROTARY DRILL F/11051 TO 11066. 4.00 CXECK~F/[LQU.~H TO..~S~9~.PUMP D~R~ JgB.POX EL BIT. TIME (~RS CUM. ROT. HRS ROTATING MUD MOTOR 5.50 TRIPPING ~1.50 Ic&c REAMING .50 SURVEYS JET REPAIRS FISHING NIP UP/DOUN /BOP/UH TESTING BOP RUNNING CASING CEMENTING .... PICKUP/LAY DOUN DS .... INSPECT BHA .... RIG UP/TEAR DOUN .... UAIT ON UEATHER/MAT .... EVALUATION .... CORING OTHERS 528.75 5.OD PI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM 'A" UELL A41A-11 UORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R PRESENT ACTIVITY: TRIPPING PROG. DEPTH PRESENT DEPTH FOOTAGE DRILLED 130 SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 7765 UATER DEPTH 80 / 12170 ELEVAT. KB TO MSL 116.0 DATE !o_z!!/9[ 11196 DIST. KB TO BHF 38.4 DAY 67 NLTA LTH/YTD ___/___ EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 918 LAST BOP TEST !~L~/_~ LAST CSG TEST !~L~/9~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 1050 @ 20 PP2 @ KILL SPEED 1650 @ 30 SUMMARY OF OPERATIONS (SHO~ HOURS FOR EACH OPERATION) : .50 TOOH ~LAST 30 STDS. ~ET~ 2.00 BHA - STD.._~BAC._._~_KD__~C'S_:P~__!.I~_JI'~_2__Z~8"._~'_~P___~DRIFT & CIRC THROUGH SAME[ ~/U BiT & 1.15 DEG MOTOR - SURFACE TEST MgD 4.00 TIH TO SHOE - FILL PIPE & TEST MUD @ 5620' 1.00 CUT & SLIP 100~ DRLG. LINE 1.00 TIH - TAG COAL a 10~830 - REAM 8.50 ROTARY DRILL ~_/_.M_OTO.___~R F.__~Rg~__1~6~TO__1__1~!9_~6~_.______ .50 SURVEY & PUMP PILL 1.00 TOOH FOR BIT 1.00 RIG REPAIR - ROLLER ON AR300 3.00 FINISH TOOH FOR BIT I .50 BHA IADC DULL GRADE B_I! #.__~22_:_._3-8_-ST:Ii. AcE-l__/16-RG-LOG #23 - 4-4-SD-A- F- I-~T-HRS #24 - 4-4-UT-A-E-I-RG&SD-HRS #25 - 4-4-gT-A-E-I-ER-HRS #26 - 4-4-~T-A-E-I-ER-HRS #27 - 5-6-~T-A-E-I-RG&CT-PR&HRS T I ME ~.HRS2 ...... CUM. ROT. HRS 537.25 ROTATING 8.50 MUD MOTOR TRIPPING 9.50 C & C REAMING SURVEYS .50 JET REPAIRS 1.00 FISHING NIP UP/DOUR /BOP/UH TESTING BOP /UH RUNNING CASING CEMENTING PICKUP/LAY DOUN DS 3.50 INSPECT BHA RIG UP/TEAR DOUN UAIT ON I./EATHER/MAT EVALUATION CORING OTHERS I .00 SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" UELL A41A-11 UORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: TESTING BOPS PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE !o.~!~/9~ PRESENT DEPTH 11313 DIST. KB TO BHF 38.4 DAY 6~ FOOTAGE DRILLED 117 NLTA LTH/YTD ___/_~ EST. DAY 4~ SIZE OF LAST CSG 5.000 LTA LTH/YTD / DAYS +/- · DEP. OF LAST CSG 10743 DAYS SINCE LAST LTA 919 gATER DEPTH 80 LAST BOP TEST ~0~/9~ LAST CSG TEST ~0/~/9~ / BHA INSPECTION (CUM. ROT HAS) PP1 @ KILL SPEED 125~ @ 20 PP2 @ KILL SPEED 1700 @ 30 SUMMARY OF OPERATIONS (SHO~ HOURS FOR EACH OPERATION) : 5.00 [~IT #28 - FILL PIPE & TEST MUD @ 5620~ & SHOE NOTEI REAMED THROUGH COAL @ ~:~30' .50 UASH & REAM TO BOTTOM 10.50 ROTARY DRLG. ~_Z!.15 DEG. MOTOR FROM 112196' TO 11.,3J3' .50 SURVEY. 4.50 TOOH 1.00 BHA 2.00 PULL NEAR BUSHING - SET TEST PLUG - TEST BOPS IADC DULL GRADE BIT #28 - 6-7-UT-A-F#3-1__/16-ER&CT-HRS NOTIFIED AOGCC OF BOP TEST - DECLINED CUM. ROT. HRS 547.75 ROTATING 10.50 MUD MOTOR TRIPPING 9.50 C&C REAMING .50 SURVEYS .50 JET REPAIRS FISHING NIP UP/DOUN /BOP/~H TESTING BOP /UH 2.00 RUNNING CASING CEMENTING PICKUP/LAY DOUR DS 1.00 INSPECT BHA RIG UP/TEAR DOUR UAIT ON UEATHER/MAT EVALUATION CORING OTHERS PI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM UELL A41A-11 UORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ · H PRESENT ACTIVITY: TRIPPING PROG. DEPTH 12170 PRESENT DEPTH 11430 FOOTAGE DRILLED 117 SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 10743 WATER DEPTH 80 / ELEVAT. KB TO MSL 116.0 DATE ~0/~/9~ DIST. KB TO BHF 38.4 DAY _~6~ NLTA LTH/YTD ___/___ EST. DAY ...~4~ LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA ~ LAST BOP TEST !gZ!~/9l LAST CSG TEST !0_/__~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 1220 @ .~2~ PP2 @ KILL SPEED 1580 @ _~ SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : 3.50 TEST BOPS & RELATED EQUIPMENT 5.00 TIH TO SHOE..~/BIT #29 & 1.15 DEG MOTOR - FILL PIPE @ 5880' &SHOE .50 TIH TO 1~,8~_- R/U TOP DRIVE TO GET PAST COAL 10.00 ROTARY DRLG g[~OTOR FROM 11.z.~13' TO .50 SPOT 20 BBL 20,#/BBL LCM PILL ON BOTTOM 4.50 TOOH FOR BIT NOTE[ HOLE STARTED TAKING FLUID @ 11~3._~.~.__(.~030 HRS~ - LOST APPROX. 10 - 18 BBLS,(2-~ BB~H/_.B.~.}.~.. HOLE TAKING PROPER AMOUNT OF FLUID ON TRIP OUT. CUM. ROT. HMS 557.75 ROTATING 10.00 MUD MOTOR TRIPPING ~0.00 C & C .50 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOUR /BOP/UH TESTING BOP /UH 3.50 RUNNING CASING CEMENTING PICKUP/LAY DOUR DS INSPECT BHA RIG UP/TEAR DOUR UAIT ON ~EATHER/MAT EVALUATION CORING OTHERS SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A41A-11 UORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY:-TRIPPING PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE PRESENT DEPTH 11545 DIST. KB TO BHF 38.4 DAY _~ FOOTAGE DRILLED 115 NLTA LTH/YTD / EST. DAY .~4~ SIZE OF LAST CSG 5.000 LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 10743 DAYS SINCE LAST LTA WATER DEPTH 80 LAST BOP TEST ~Z!~/9~ LAST CSG TEST ~0/~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 1675 @ 20 PP2 @ KILL SPEED 2160 @ 30 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.50 ~/U 12 JTS 2 ,7/~"DP - CIRC. THROUGH SAME - STD BACK IN DERRICK 1.50 BHA 2.00 TEST MWD - TRIED TO PLUG - CIRC & CLEAN UP PUMP LINES OF LCM 4.50 TIH UB_.UB~.#30 & 1.15 DEG MOTOR 1.00 ~/U_~Op D~Vg&_~ORK THROUGH COAL @ 1_,9_c0 ~O..~.~_~_].11,14~'__=_REAM TO BOTTOM & SURVEY 1.00 ROTARY DRLG FROM 71.~30~ TO_!1,43__Z.7' .50 SLOW DO~N PUMP RATE & CIRC OUT LCM PILL · 50 ATTEMPT TO ORIENT MOTOR & DRILL - MUD JAMMING .50 ROTARY DRLG FROM 6.00 ORIENT &.SLIDE FROM__1~7._~:~O:~[,512__ 3 50 ROTARY DRLG FROM 11~12 T.___..~_011_~.~45' .50 SURVEY & PUMP PILL 1.00 TOOH FOR BIT IADC DULL GRADE BIT #29 - 6-5-UT-H-E-I-ER-HR FIRE ALARM ON 10-12-95 - FALSE ALARM BAY #4 HOLE TAKING 2-3 BB~R WHILE DRILLING TIME CUM. ROT. HRS 568.75 ROTATING 5.00 MUD MOTOR 6.00 TRIPPING 5.50 C & C 2.50 REAMING 1.00 SURVEYS 1.00 JET REPAIRS FISHING NIP UP/DOUR /BOP/UH TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DO~N DS 3.00 INSPECT BNA RIG UP/TEAR DOUR UAIT ON UEATHER/MAT EVALUATION CORING OTHERS -- ~ 'EPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: DRILLING PROG. DEPTH 1._~217..._.~0 PRESENT DEPTH 1__1~ FOOTAGE DRILLED 110 SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 10743 WATER DEPTH 80 / SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 3.50 TOOH ~__~BIT #30 1.00 BHA - ADJUST MOTOR TO 1.83 DEG 4.50 TIH ~BIT #31 1.00 CUT & SLIP DRLG. LINE 1.00 WORK PAST COAL'S @J~,83~0.' .50 ROTARY DRLG. FROM 1!~54~, T0_11.~49' 7.50 ORIENT & MOTOR DRLG. FROM 11_J.~.54~' TO 11,598' 4.00 ROTARY DRLG. FROM 11,598~ T~_~39' 1.00 ORIENT & SLIDE FROM 11,~39~ TO 1'1,655' IADC DULL GRADE BIT #30 - 5-6-BT-H-E-1/16-WT&ER-HRS ELEVAT. KB TO MSL 116.0 DATE !o_Z!~£~ DIST. KB TO BHF 38.4 DAY -~! NLTA LTH/YTD / EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST ETA 922 LAST BOP TEST !g£!~/~.! LAST CSG TEST !gZg~Z2~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 1780 @ 20 PP2 @ KILL SPEED 2250 @ 30 NOTEi SLO~ P RATE ON BIT #31 DUE TOO ORIENTI____~N~SLIDE MOST OF RUN. T I M E_.(.HR S1 ....... CUM. ROT. HRS 581.25 ROTATING 4.50 MUD MOTOR 8.00 TRIPPING 8.00 C & C REAMING 1.00 SURVEYS .50 JET REPAIRS FISHING NIP UP/DOWN /BOP/IJH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOUN DS .1.00 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 1.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A41A-11 WORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: TRIPPING PROG. DEPTH 12170 PRESENT DEPTH 11744 FOOTAGE DRILLED 89 SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 10743 WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE !o/!~E DIST. KB TO BHF 38.4 DAY 72 NLTA LTH/YTD / EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 923 LAST BOP TEST ~~ LAST CSG TEST ~~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 1400 @ 20 PP2 @ KILL SPEED 1800 @ 30 SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : 1.00 ORIENT/SLIDE FROM 11~655' TO 11,668' .50 ROTARY DRLG. FROM !!~6._~68__' TO 11~Z__2' 4.00 TOOH I .00 BHA 3.50 TIH TO SHOE ~/BJT #32 & 1.15 DEG MOTOR - FILL PIPE @ 6300' & SHOE 1.00 WORK THROUGH COALS @_10~30' & !!~14o' .50 ROTARY DRLG. FROM 11,672' TO _1__1~.~677' NO.___~T~; STARTED LOOSING FLUID ~APPROX. 20 BBL IN 30 .5~ REDUCE PUMP RATE TO 29 SPM - CIRC BOTTOMS UP. 5.00 ROTARY DRLG.: U/~9 SPM FROM 1!~67_~7'__T0 NOTE~ APPEARED TO DRILL HC COAL @ 11,696' 1.00 CIRC. @ 20 SPM ~NO LOSS~ FOR SAMPLES 1.00 ROTARY DRLG. FR~ff 11~730' TO .50 PUMP PILL - CHECK FLOW 4.50 TOOH FOR CLEAN OUT ASSEMBLY - STOPPED @ SHOE & MONITOR WELL FOR LOSS NO LOSS IADC DULL GRADE BIT #31 - 6-6-BT-F#3-1~16"-ER&WT-HRS NOTEi TOTAL FLUID LOSS FROM START OF DRLG. TO STOP gAS 79 BBL. LOSSES WERE FROH 3 TO 11 BBL/flR. NOTE~ HIGH DAILY COST DUE TOO 5" CASING & CENTRALIZER ADDITION TO TIME_~I ....... CUM. ROT. HRS 589.25 ROTATING 7.00 MUD MOTOR 1.00 TRIPPING 12.00 C & C 2.OO REAMING 1.00 SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 1.00 INSPECT BHA RIG UP/TEAR DOWN UAIT ON UEATHER/MAT EVALUATION CORING OTHERS i~.-S~EPI ALASKA DAILY DRILLING REPORT =,. PAGE 1 OF 1 ~IG NAME PLATFORM "A" :IELD MIDDLE GROUND SHOAL _EASE PLATFORM "A" JELL 4414-11 JORK ORDER 739930 SIDE TRACK )RILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: TRIPPING PK-~. DEPTH PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 5TM OEP. OF LAST CSG 10743 WATER DEPTH 80 / 12170 ELEVAT. KB TO ,,$L 116.0 DATE ~ZL~ 11744 DIST. KB TO BHF 38.4 DAY 73 NLTA LTH/YTD / EST. DAY 45 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 924 LAST BOP TEST ~~ LAST CSG TEST ~L~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 1350 @ 20 PP2 @ KILL SPEED 1600 @ 30 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : .50 TOOH FOR CLEAN OUT ASSEMBLY 2.50 BHA - LZD MOTOR & MONELS - P/U STEEL ASSEMBLY 4.50 TIH ~BIT RR #32 JNO FLOAT IN DRILL STRINGZ 9.00 REA_M_FR~l._~.~_~O88~._~.TD_l_].l.z. ZT~4' ~OT~z LOST 16 BBLS MUD ~HILE REAMING .50 CIRC. 1.00 SHORT TRIP TO SHOE {SLICK HOLE~ .50 TIH TO BOTTOM ~SLICK HOLE~ 1.50 CIRC. & MIX PILL 4.00 TOOH FOR LOGS IADC DULL GRADE BIT #32 - 3-4-BT-H-E-I-ER-TD .. TIM~_~ ......... CUM. ROT. HRS 589.25 ROTATING MUD MOTOR TRIPPING ~0.50 C & c 2.00 REAMING 9.00 SURVEYS JET REPAIRS FISHING NIP UP/DOUN /BOP/UH TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DOUN DS 2.50 INSPECT BHA RIG UP/TEAR DOgN gAIT ON gEATHER/MAT EVALUATION CORING OTHERS SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM UELL 4414-11 ~ORK ORDER 739930 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTZVITY: DRILLING PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE ~0__~/9~ PRESENT DEPTH 11908 DIST. KB TO BHF 38.4 DAY 74 FOOTAGE DRILLED 164 NLTA LTH/YTD / EST. DAY 45 SIZE OF LAST CSG 5.000 LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 10743 DAYS SINCE LAST LTA 925 ~ATER DEPTH 80 LAST BOP TEST ~0.~Z/9~ LAST CSG TEST ~Z~/9~ __/ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 1220 ~ 20 PP2 ~ KILL SPEED 1440 @ 30 SUMMARY OF OPERATIONS (SHO~ HOURS FOR EACH OPERATION) : 1.50 TOOH TO LOG '6.50 LOG U/SCHLUMBERGER (GR/DENSITY) NOTE; MADE,(2) RUNS - FIRST DENSITY TOOL UAS BAD 1.00 BHA 3.50 TIM ~/BIT #33 & STRAIGHT MOTOR 3.00 CIRC & CONDITION MUD g SHOE .50 TIH (NO PROBLEMS) 8.00 ROTARY DRLG ~/STRAIGHT MOTOR FROM 11.744~ TO 1!~908" NOTE; LOST APPROX. 20 BBL MUD (FROM TIH TO 0600 HRS2 NOTE; LOGS SHOWED ~E ARE IN HF - NEED TO DRILL 200 - 260" NOTE; SUELLED CONNECTIONS ON JARS UHILE REAMING HOLE (PRIOR TO LOG- GING) NOTE; TOTAL CIRC; HRS ON MOTOR @ 0600 HRS = 11 T Z M E_~.HR S2 CUM. ROT. HRS 597.25 ROTATING 8.00 MUD MOTOR TRIPPING 5.50 C & C 3.00 REAM I NG SURVEYS JET REPAIRS FISHING N I P UP/DOUN /BOP/UH TESTING BOP /IJH RUNNING CASING CEMENTING PICKUP/LAY DOIJN DS 1.00 INSPECT BHA RIG UP/TEAR DOUN UAIT ON UEATNER/MAT EVALUATION 6.50 CORING OTHERS RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A"" WELL A41A-11 WORK ORDER 739930 SIDE TRACK ,EPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 PROG. DEPTH 12!Z~ ELEVAT. KB TO MSL 116.0 DATE PRESENT DEPTH 12047 DIST. KB TO BHF 38.4 DAY 75 FOOTAGE DRILLED 139 NLTA LTH/YTD / EST. DAY 45 SIZE OF LAST CSG 5.000 LTA LTH/YTD ___/___ DAYS +/- DEP. OF LAST CSG 10743 DAYS SINCE LAST LTA 92~ WATER DEPTH 80 LAST BOP TEST !~!~ LAST CSG TEST DRILLING FOREMAN: SELTZ R H / PRESENT ACTIVITY: TRIPPING TO RUN SLOTTED LINER SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.00 ROTARY DRLG_~ZSTRAiGHT MOTOR FROM 1.~07' T0.11~25, 4.50 TOOH FOR BIT ~.__s_o BNA TIN TO SHOE ._~D~ SLIP & CUT DRLG LINE .50 TIH - REAM 15" TO BOTTOM 8.50 ROTARY DRLG_~[STRAIGHT MOTOR FROM 11_~.92~' TO 12~047' 2.00 CIRC. & CONDITION MUD PRIOR TO RUNNING SLOTTED LINER 1.50 TOOH HOTEl CONTACTED BLAIR WONDZELL_~_JAOGCC AND ASKED TO WAIVE WEEKLY BOP TEST DUE RUNNING COMPLETION - PERMISSION GRANTED. NOT~/ TOTAL CIRC. HRS ON MUD MOTOR = 24 ESTIMATED TOP OF MC COAL 11~9__80' IADC DULL GRADE BIT #33 - 5-6-BT-H-E-I-ER&WT-HRS BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED PP2 @ KILL SPEED 1050 @ 20 1480 @ 30 TIME_~ CUM. ROT. HRS 607.75 ROTATING 10.50 MUD MOTOR TRIPPING 10.00 C & C 2.00 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DO~N /BOP/~H TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS .50 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 1.00 _. _ RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LEASE PLATFORM "A" UELL A41A-11 UORK ORDER 73993.~0 SIDE T~ACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: TRIPPING SWEPI ALASKA DAILY DRILLING REPORT PROG. DEPTH 12170 ELEVAT. KB TO MSL PRESENT DEPTH 12047 DIST. KB TO BflF FOOTAGE DRILLED NLTA LTH/YTD SIZE OF lAST CSG 5.000 LTA 1TH/YTD DEP. OF LAST CSG 10743 DAYS SINCE LAST LTA UATER DEPTH 80 / SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 4.5._~0 TOOH TO RUN LINER 1.0__._.~0 L/D. BHA PAGE 1 OF 1 116.0 DATE 38.4 DAY / EST. DAY / DAYS +/- 927 LAST BOP TEST JD/I~/9~ LAST CSG TEST ~0_~/_~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED !~ @ 20 PP2 @ KILL SPEED !~ @ ._~3~ 9.5____~0 ~/U & RUN 44 JTS 3.5" 9.3# SLOTTED LINER.~1352, THREADS OFFZ - LINER SET a 12,045, - HANGER TOP @_1__00.,_680, ~ TOOH~TTING TOOL 5.0_~0 P U_~5?,l.66~._3_.~.~O2_#_W__AS~H STRING - TIH_.(._SP__ACED OUT 5" & 7N SCRAPERS~__ ~ __~0~; TOOK 24 MIN. PUMPING 2 BBLJMIN FOR BALL TO SEAT IN SETTING ~ TOOL. SHEARD @ 2400 PSI. IADC DUL___~_L GRADE BIT #34 - 3-4-WT-A-E-I-ER-TD .... ~OTE; COULD NOT RUN SLOTTED LINER IN ORDER STRAPPED DUE TO RU~/ :__ COrrOSION IN SLOTS - SORTED & RAN ONLY COATED PIPE. T I M E ~RS2 I CUM. ROT. HRS J ROTATING J MUD MOTOR J TRIPPING Ic&c J REAMING J SURVEYS J JET J REPAIRS J FISHING J NIP UP/DOWN /BOP/WH J TESTING BOP /WH ! RUNNING CASING J CEMENTING J PICKUP/LAY DOWN DS J INSPECT BHA J RIG UP/TEAR DOWN J WAIT ON WEATHER/MAT J EVALUATION J CORING J OTHERS 607.75 9.5~ 1.00' S~EPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM UELL A41A-11 UORK ORDER 739930 SIDE TRACK DR[LLING FOREMAN: SELTZ R H PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE ~L~1,/9~ PRESENT DEPTH 12047 DIST. KB TO BHF 38.4 DAY 77 FOOTAGE DRILLED NLTA LTH/YTD / EST. DAY 45 SIZE OF LAST CSG 3.500 LTA LTH/YTD ___/___ DAYS +/- DEP. OF LAST CSG 12045 DAYS SINCE LAST LTA 928 ~ATER DEPTH 80 LAST BOP TEST ~0/~/9~ LAST CSG TEST ~0_~/_~ / BHA INSPECTION (CUM. ROT HAS) PRESENT ACTIVITY: PREPARE TO SET DB PACKER SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 4.00 TIH ~/~ASH STRING & SCRAPERS PP1 @ KILL SPEED @ 20 PP2 @ KILL SPEED g 30 7.00 BREAK CIRC. & RECORD PUMP PRESSURE & STKS PRIOR TO STABBING INTO PACK OFF - STING INTO PACK-OFF a ~2,~0, - CIRC 8.4 MIN OIL MUD FOR (~__ .... ANNULAR VOLUMES - PUMP 25 BBL S~EEP FOLLOWED BY 512 BBL DIESEL - CHECK FLOW (NOT FLOWING) 1.50 ATTEMPT TO TOOH - ~ELL OUT OF BALANCE ~FLO~ING OVER DRILL PIPE~ - INSTALL FLOOR VALVE & RUN HOSE TO TRIP TANK - FLO~ UELL & LET EQUALIZE 4.50 TOOH 3.00 L/D !~6" ~ASH STRING 4.00 ~ ~_3[8" RE-ENTRY ~[~__~~/8" 4.7# L-80 8RD TBG_~=O~IS=XN___ ~XRRLE, (1)..~ 2 3/8~_T~ (1) ~_3/8" PU~_JT, BAKER SEAL BORE E[[=~____ BAKER "DB" PERMANENT PKR. ~[2.688# MIN. BORE [~2S S~g) - TIH - SET PKR a 8417~ - RE-ENTRY GUIDE g 8502~ AFTER PUMPING 325 BBL DI~SEL,=6TTEMPT TO PULL OUT OF LOCATOR PACK-OF~, SLICK STICK UAS ST~CKz.._~ORKED PiPE & PULLED 35K OVER STRING ~T. TO FREE. NO PROBLEMS AFTER PULLING FREE. T Z ME._~RS~ CUM. ROT. HAS 607.75 ROTATING MUD MOTOR TRIPPING 12.50 C & C 7.00 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOUN /BOP/~H TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DO~N DS 3.00 INSPECT BHA RIG UP/TEAR DO~N UAIT ON UEATHER/MAT EVALUATION CORING OTHERS 1.50 S~EPI ALASKA DALLY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "Au FIELD MIDDLE GROUND SHOAL LEASE PLATFORM #A" NELL A41A-11 ~ORK ORDER 739930 SlOE TRACK · PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE ~0_~ ~/_~ PRESENT DEPTH 12045 DIST. KB TO BHF ___~._~ DAY 78 FOOTAGE DRILLED NLTA LTH/YTD / EST. DAY 45 SIZE OF LAST CSG 3.500 LTA LTH/YTD / DAYS +/- ~- DEP. OF LAST CSG 12045 DAYS SINCE LAST LTA 929 ~ATER DEPTH __8~0 LAST BOP TEST ZO/!A/9~--~AST CSG TEST ~0/~/9~ DRILLING FO~EM~N: SELTZ R H PRESENT ACTIVITY: FINISH RUNNING TUBING SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : 2.50 FINISH TOOH ~/3 1/~" DP - TIH~35 STDS 2 ~8" DP 1.00 ~UT/SLIP DRLG LINE 6.50 [/D (204) ITS 2 7/8- DP BHA INSPECTION (CUM. ROT HRS) PPl g KILL SPEED g 20 PP2 g KILL SPEED @ 30 _ NOTE; TOOK ON 2~,000 GAL DIESEL & 13,000 GAL UATER FROM::LV MONARCH ~NILE LAYING DO~N DP (CRANE CREU UAS "HUCKADY-BUCKINa)... ~ CHANGE RAMS & ATTEMPT TO TEST BOPS TEST PLUG UOULD NOT SEAT 10.5~0 HOLD PRE-dOB SAFETY MEETING - R/p & RUN 2 ~" & 2,?/8~ COMPLETION 3 1/.2" SLOTTED lINER, 228 JTS 2 ~/8" DP, 500 BBL TAN~,:~O0 BBL TANK, 57 ITS 1.66" DP, (5) ~ 7/8" STEEL DC~._.(.~) 3 1/8" MUD MOTORS, (1) ~1~4" DRLG JAR, (!):3 !/4- BUMPER SUB~_PLTS UASH STRING TO0,[~ DUMPSTE~,~_g~OIL TOTE, CHEMICAL TOT__E~._~&_RACK OF DRUMS. NOTE; BACK LOADED BOAT AFTER TAKING FUEL & WATER - SENT IN 43 ITS T i M E._.C_~ R S.Z CUM. ROT. HRS. 607.75 ROTATING MUD MOTOR TRIPPING 2.50 C&C REAMING SURVEYS JET REPAIRS FISHING NIP UP/OOUN /BOP/UH TESTING BOP /UH 3.50 RUNNING CASING 10.50 CEMENTING PICKUP/LAY DOI~N DS 6.50 INSPECT BHA RIG UP/TEAR DOUN UAIT ON UEATHER/MAT EVALUATION CORING OTHERS 1.00 SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIELD MIDDLE GROUND SHOAL LEASE PLATFORM UELL A41A-11 UORK ORDER 739930 SIDE TRACK DRILLING FOREMAN= SELTZ R H PRESENT ACTIVITY= FINISHING UP PROG. DEPTH 12170 ELEVAT. KB TO MSL 116.0 DATE ~0_~2__3/9~ PRESENT DEPTH 12045 DIST. KB TO BHF 38.4 DAY 79 FOOTAGE DRILLED NLTA LTN/YTD ___/___ EST. DAY 45 _ SIZE OF LAST CSG 3.500 LTA LTH/YTD ___/___ DAYS +/- DEP. OF LAST CSG 12045 DAYS SINCE LAST LTA 930 UATER DEPTH 80 LAST BOP TEST ~0/~/~ LAST CSG TEST / BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED @ 20 PP2 @ KILL SPEED ~ 30 SUMMARY OF OPERATIONS (SHOU HOURS FOR EACH OPERATION) : 1.50 STING INTO DB PKR - P/U & SPACE OUT TO LAND TBG HANGER 1.00 ~/U & CIRC 1.5 TBG VOLUMES 3.50 LAND TBG - R/U SLICKLINE LUBRICATOR & TEST TO 3500 PSI - RIH U/ "N" TEST TOOL - SET TOOL - TEST TBG TO 3500 PSi - TEST TBG X CSG ANNULUS TO 2000_psi (O.K.) : POOH U/TEST TOOL - R/D SLICKLINE UNIT .50 SET BPV .50 FLUSH DIESEL FROM LINES 1.00 CHANGE RAMS BACK TO 3.5" 10.00 ~/D BOPS - SET TREE - TEST TREE TO 5000 PSI 6.00 FINISH MAKING FINAL UELDS ON GAS INJ. LINE & FLOU LINE - INSTALL START CLEANING PITS - UORK ON DUMPING 100 BBL TANK OF ONSHORE TANK BOTTOMS INTO CUTTINGS GRINDER - START RUNNING LINES TO A12-12 NOTE; TBG. RE-ENTRY GUIDE DEPTH IS @ 8515t - 13t (DEEPER) DIFFERENCE BETUEEN TBG & DRILL PIPE MEASUREMENTS. UIRELINE MEASUREMENT CONFIRMED. NOTEI BACK LOADED M/V CHAMPIO~=MIN C)I~L_._.MUD PRODUCTS & EXCESS TBG. T I M.E ( H R S.)._____~ CUM. ROT. HRS 607.75 ROTAT I NG MUD MOTOR TRIPPING C&C -1-~ REAMING SURVEYS JET REPAI RS FISHING NIP UP/DOI./N /BOP/UH 10.00 TESTING BOP /~H RUNNING CASING 1.50 CEMENTING PICKUP/LAY DOIJN OS INSPECT BHA RIG UP/TEAR UAIT ON UEATHER/MAT EVALUATION CORING OTHERS 11.50 ; TIME: 09:00-1'2:30; 16:30-19:00; . . 19:00-2~.'-~ ~ :.. · · DALLY REPORT A41A-11LN AFE# - 739941 . RIO UPiE~I'~UMBERGER AND PRESSURE TEST LUBRICATOR: TO 15(X)~. ! HOLD ERE-JOB SAFETY MEETING. · ': I~OCATE COLLARS AND TIE IN. PERFORATE FROM 10E~36-10632. PooH. PERFORATE FROM 't0632-10598. POOH. GUNS FIRED. ' PERFORATE FROM 10598-1~. POOH. GUNS FIRED. : PERFORATE'FROM 10564-10530. POOH. GUNS FIRED. ~ RIG--DONVN ,~CHLUMBERGER. \ Client .... · SHELL WE~T~RN E & P INC Field ..... : MIDDLE GK~ SHOAL, A-PLATFORM Well ...... : A41A- llL~~ Vert sect.: 5.04 de~-~ DD en~nr..: Gary P~ Units "FEET ~ ~lhead coordinates. , .: 0,0 S MEAS INCLN DIRECTION T DEPTH ANGLE AZ IMUTH '7 0 0. O0 0. O0 7 42 1 , 05 221 · 00 7 100 0 . 37 269 . 00 7 200 0 . 52 291 . 00 7 300 0.53 306.00 400 0.60 273 .00 500 0.78 263 .00 600 0 78 269 00 700 2.48 332 .00 800 5.02 357.00 Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 RECORD OF SITRVEY VERTICAL-DEPTHS TVD SUB-SEA 0.0 -116.0 42.0 - 74.0 100.0 -16.0 200.0 84.0 300.0 184.0 400.0 284.0 500.0 384.0 600.0 484.0 699.9 583.9 799.7 683.7 7 900 7.57 3.00 899.1 783.1 7 1000 10.50 7.00 997.9 881.9 7 1100 12.82 5.00 1095.8 979.8 '7 1200 14.48 1.00 1193.0 1077.0 7/GI-RO ^Station T~es: SECTION COORDINATES - FROM DEPART Wellhead 0.0 0.0 N 0.0 E -0.3 0.3 S 0.3 W -0.8 0.? S 0.8 W -0,7 0.5 S 1.5 W -0.3 0.1 S 2.3 W -0.1 0.2 N 3.2 W -0.2 0.1 N 4.4 W -0.5 0.0 N 5.8 W 1.3 1.9 N 7,5 W '7.4 8.2 N 8.7 W 18.3 19.2 N 8.6 W 34.0 34.8 N 7.2 W 54.2 54.9 N 5.1 W 77.8 78.4 N 3.9 W 12/12/95 Position calc.: Minimum Curvature Dogleg calc...: Lubinski Survey Date...: 12/12/95 KB Elevation..: 116.00 ft Reference ..... : AFE#739930/Job#36543 Magnetic dcln.: +22,598 (E) ALASKA Zone 4 X Y 232851.0 2485893.9 232850.7 2485893.7 232850.1 2485893.3 232849.4 2485893.4 232848.6 2485893.9 232847.7 2485894.2 232846.5 2485894.2 232845.2 2485894.1 232843.5 2485896.1 232842.4 2485902.4 232842.8 2485913.3 232844.6 2485928.9 232847.1 2485948.9 232848.8 2485972'.5 Pg: 1 CLOSURE DISTNCE 0.0 0.4 1.0 1.6 2.3 AZIMUTH 0.00 221.00 228.55 250.57 267.45 3.2 4.4 5.8 7.7 12.0 273.50 271.83 270.46 284.58 313.29 21.0 35.5 55.1 78.5 335.79 348.37 354.71 357.15 DL/ 100 0.00 2,50 1.46 0.22 0.14 0.33 0.22 0.08 2.24 2.96 2.63 3 .00 2.35 1.91 0 ,q N 0 (Anadrill '~c)95 AglAllD2 2.5b.04 8:35 AM D) A41A-11LN MEAS INCLN DIRECTION DEPTH ANGLE AZIMUTH 1300 15.42 353.00 1400 16,90 346.00 1500 19,52 344.00 1600 20.72 345,00 1700 21.78 345,00 1800 23.12 346.00 1900 23.58 346.00 2000 23.47 345.00 2100 24.18 345,00 2200 25,08 345,00 VERTICAL--DEPTHS TVD SUB-SEA 1289.6 1173.6 1385.6 1269.6 1480.6 1364.6 1574.5 1458.5 1667,7 1551.7 1760.1 1644.1 1851.9 1735.9 1943,6 1827,6 2035.1 19].9.1 2126.0 2010.0 SECTION DEPART RECORD OF SURVEY COORDINATES-FROM Wellhead 103.3 104.1 N 5.3 W 130.0 131~4 N 10.4 W 159.4 161.6 N 18.6 W 191.6 194.8 N 27.7 W 225.6 229,8 N 37.1 W 261.6 266.7 N 46.7 W 299.1 305.2 N 56,3 W 336.7 343.8 N 66.3 W 374·6 382.8 N 76.7 W 413.8 423.1 N 87.5 W A3~ASKA Zone 4 X Y 232848.0 2485998.2 232843,5 2486025.6 232836.1 2486055.9 232827.7 2486089.3 232819.1 2486124.5 232810.4 2486161.7 232801.7 2486200.3 232792.5 2486239.2 232783.0 2486278.4 232773.1 2486318.9 Page 2 12/12/95 CLOSURE DISTNCE AZIMUTH DL/ 100 104.3 357.09 2.26 131.9 355.46 2.45 162.7 353.45 2.69 196.7 351,89 1.25 232.7 350,82 1.07 270.8 350.07 1.39 310.3 349.55 0.47 350.2 349.09 0.42 390.5 348.67 0.72 432.1 348.32 0,90 ~0 0 ~0 ee 7 2300 25.42 345.00 7 2400 24.93 344.00 7 2500 24.68 344.00 7 2600 24.62 344.00 7 2700 24.30 343.00 2216.5 2100,5 2307.0 2191.0 2397.7 2281.7 2488.6 2372.6 2579.6 2463.6 453.9 464.3 N 98.5 W 493.7 505.3 N' 109.9 W 532.9 545.6 N 121.5 W 571.8 585.7 N 133.0 W 610.3 625.4 N 144.7 W 232763.0 2486360.4 232752,6 2486401.6 232741,9 2486442,2 232731.4 2486482.5 232720.5 2486522.5 474,7 348,02 0.33 517.1 347.73 0.64 559.0 347.45 0.25 600.6 347.21 0.07 642.0 346.97 0.52 2800 23.98 343.00 2900 23.73 342.00 3000 23.50 342.00 3100 23,20 341.00 3200 23 52 342 00 · . 7 3300 23.70 342.00 7 3400 23.65 342.00 7 3500 23.48 344.00. 7 3600 23.93 342.00 7 3700 24.92 343,00 2670.9 2554.9 2'762.4 2646.4 2854.0 2738,0 2945.8 2829.8 3037.6 2921.6 3129.2 3013,2 3220.8 3104.8 3312.5 3196.5 3404.0 3288.0 3495.1 3379,1 648.2 664.5 N 156.7 W 685.6 703.1 N 168.8 W 722.4 741.2 N 181.2 W 758.8 778.8 N 193.8 W 795.1 816.4 N 206.4 W 832.0 854.5 N 218.7 W 868.9 892.7 N 231.2 W 906.0 930.9 N 242.8 W 943.2 969.3 N 254.6 W 981.4 1008.8 N 267,0 W 232709.5 2486561.9 232698,2 2486600.7 232686.7 2486639.1 232675.0 2486676,9 232663.2 2486714.8 232651.7 2486753.2 232640.2 2486791,6 232629.4 2486830.1 232618,5 2486868,8 232607.0 2486908.5 682.8 346.73 0.32 723.1 346.50 0.48 763.0 346.26 0,23 802.5 346.03 0,50 842.1 345.81 0.51 882,0 345.64 0.18 922.1 345.48 0.05 962.1 345,38 0,82 1002.2 345.28 0.92 1043.5 345.17 1.07 7 3800 26.05 344.00 3585.3 ,.. ^Station Types: 7/GyRo (~adrill (c}95 A41AllD2 2.5b.04 8:35 AM D) 3469,3 1021.4 1050.0 N 279,2 W 232595.7 2486950.1 1086.5 345.11 1.21 A41A-11LN 7 7 7 7 7 MEAS DEPTH INCLN ANGLE 3900 27.17 4000 28.35 4100 29.22 4200 29.78 4300 28.92 )4400 28.97 4500 29.53 4600 30.20 4700 27,92 4800 26..70 -_ DIRECTION AZIMUTH 343.00 343,00 343.00 343,00 342.00 343.00 343.00 344.00 349.00 357.00 VERTICAL-DEPTHS SECTION TVD SUB-SEA DEPART 3674.8 3558.8 1063.1 3763.2 3647.2 1106.3 3850.9 3734.9 ].150,9 3937.9 3821.9 1196.5 4025.1 3909,1 1241.8 4112.6 3996.6 1286,5 4199.9 4083.9 1331.8 4286.6 4170.6 1378.1 4374.0 4258.0 1424.1. 4462.9 4346.9 1468.9 7 4900 27.93 7 5000 29.18 7 5100 29.42 7 5200 29.73 7 5300 29.32 359.00 4551.7 4435,7 1514.4 359.00 4639.6 4523.6 1561.9 359,00 4726.8 4610,8 1610.6 358.00 4813.7 4697.7 1659.6 359.00 4900.7 4784.7 1708.6 5400 29.12 5500 29.07 5600 28.23 5700 26.68 ~5800 25.13 5900 25.85 6000 26.22 6100 25.55 6200 25.02 6300 24.52 RECORD OF SURVEY 7 6400 25,08 ^Station Types: COORDINATES-FROM Wellhead ? 1093.0 N 292.0 W 1137.5 N 305.6 W 1183.6 N 319.7 W 1230.7 N 334.1 W 1277.4 N 348.8 W 1323.5 N 363.3 W 1370,3 N 377.6 W 1418.0 N 391,8 W 1465.2 N 403.2 W 1510.6 N 408.8 W 1556.5 N 410.4 W 1604.3 N 411.2 W 3.653,2 N 412,1 W 1702,5 N 413.4 W 1751.8 N 414.7 W 4.00 4988.0 4872.0 1757.3 1800.6 N 413.4 W 10.00 5075.4 4959,4 1805.8 1848.8 N 407.5 W 12.00 5163,2 5047.2 1853.5 1895.8 N 398.4 W 13.00 5251.9 5135.9 1899.2 1940.8 N 388.4 W 14.00 5341.9 5225.9 1942.4 1983.3 N 378,2 W 13.00 5432.1 5316.1 1985.0 2025.2 N 368.2 W 1.4.00 5522.0 5406.0 2028.4 2067.9 N 357,9 W 14.00 5612.0 5496.0 2071,5 2110,2 N 347.3 W 14.00 5702.4 5586.4 2113.7 2151.7 N 337.0 W 15.00 5793.2 5677.2 2155.0 2192.2 N 326.5 W 16.00 (Anadrill (c)95 A4!AllD2 2.5b.04 8:35 AM D) 5884.0 5768.0 ,. 2196.3 2232.6 N 315.3 W AI2kSKA Zone 4 X Y 232584.0 2486993.3 232571.4 2487038.1 232558.3 2487084.5 232545,0 2487131.9 232531.4 2487178.9 232517.9 2487225.4 232504.6 2487272.4 232491.6 2487320.5 232481,3 2487367.9 232476.7 2487413.5 232476.1 2487459,3 232476.4 248'7507.2 232476.6 2487556,1 232476.5 2487605.4 232476.3 2487654,7 232478,7 2487703.4 232485,7 2487751.5 232495.9 2487798.3 232506.9 2487843,1 232518.0 2487885.3 232529,0 2487927.0 232540.3 2487969.4 232551,8 2488011.5 232563.0 2488052,7 232574,5 2488093.0 232586,6 2488133.1 Page 3 12/12/95 CLOSURE DL/ DISTNCE AZIMUTH 100 1131.3 345.04 1,20 1177.9 344.96 1.18 1226.0 344.89 0.87 1275.2 344,81 0,57 1324.2 344.73 1.00 1372.5 344.65 0,49 1421.4 344.59 0.57 1471.1 344,56 0.83 1519,7 344,61 3.33 1565.0 344.86 3.86 1609.7 345.23 1.54 1656.1 345.62 1.25 1703.8 346.00 0.23 1752,0 346.35 0.59 1800.2 346.68 0.65 1847.4 347.07 2.45 1893.1 347,57 2,92 1937.2 348.13 1.27 19'79.3 348.68 1.62 2019.1 349.20 1.61 2058.4 349.70 0.84 2098,6 350.18 0.57 2138.6 350.65 0.67 2177,9 351.10 0.53 2216.4 351,53 0.65 2254.8 351.96 0.71 ~0 o o iA- llLN MEAS INCLN DIRECTION VERTICAL-DEPTHS DEPTH ANGLE AZIMUTH TVD SUB-SEA 6500 24.62 15.00 5974.7 5858.7 6600 24.33 15.00 6065.7 5949.7 6700 23,88 14.00 6157.0 6041.0 6800 22.88 14.00 6248.8 6132.8 6900 22.15 14.00 6341.2 6225.2 7000 21.82 14.00 6433.9 6317.9 7100 21.63 15.00 6526.8 6410.8 7200 21.13 15.00 6619.9 6503.9 7300 20.58 16.00 6713.3 6597.3 7400 19.97 17.00 6807.2 6691.2 7 7500 19.68 16.00 6901,2 6785,2 7 7600 19,35 17.00 6995.5 6879.5 3 7700 19.08 19.00 7089.9 6973.9 3 7826 23.90 20.90 7207.1 7091.1 3 7920 29.40 18,40 7291.1 7175.1 8014 35.10 19.80 8108 41,10 18.70 8201 45.10 21,60 8281 47.10 19.80 8573 47.50 22,60 7370.6 7254.6 7444.5 7328.5 7512,4 7396,4 '7567.9 7451.9 7765.9 7649.9 3 9087 48.70 26.10 8109.2 7993.2 3 9202 49,90 24.00 8184.2 8068.2 3 9305 51.90 25.40 8249.2 8133.2 3 943.9 52.70 25.40 8318.9 8202.9 3 9499 52.00 23.50 8367,8 8251.8 9530 51 . 10 25 . 40 8387.1 8271.1 ,.. ^Sta¢ion Types: 3/MWD 7/GYRO (Anadrtll (c)95 A41AllD2 2.5b.04 8:35 AM D) RECORD OF SURVEY SECTION DEPART 2237.6 2278.4 2318.7 2357,9 2395.7 2432.7 2469.2 2505.1 2540,2 2574.]. 2607.4 2640.1 2672.2 2716,7 2757,5 2806,1 2862.4 2923 , 7 2979.2 3185,2 3546,1 3628,1 3703.3 3787.9 3847,6 COORDINATES-FROM ALASKA Zone 4 Wellhead X Y 2273,1 N 304.1 W 2313.1 N 293.4 W 2352.7 N 283.1 W 2391.2 N 273.5 W 2428.3 N 264.3 W 2464.7 N 255.2 W 2500.5 N 245.9 W 2535.7 N 236.5 W 2570.0 N 227.0 W 2603.3 N 217.2 W 2635.8 N 207,5 W 266'7.8 N 198.0 W 2699,1 N 187~9 W 2742.4 N 172.1 W 2782.2 N 158.0 W 2829.5 N 141.5 W 2884,3 N 122·4 W 294,3.9 N 100.5 W 299'7.8 N 80.1 W 3197.8 N 2.5 W 3546.2 N 155.3 E 3625.2 N 192.1 E 3697.8 N 225.6 E 3779.3 N 264.2 E 3836.9 N 290.5 E 3870.5 3859.0 N 300.5 E 232598.7 2488173.4 232610,4 2488213.1 232621.5 2488252.4 232632.0 2488290.7 232642.1 2488327.6 232652.0 2488363.7 232662.0 2488399.4 232672.3 2488434.4 232682.6 2488468.4 232693.2 2488501.4 232703.5 2488533,7 232713.7 2488565,5 232724,6 2488596.6 232741.4 2488639,6 232756.4 2488678.9 232773.9 2488725.9 232794,3 2488780.2 232817,5 2488839.3 232839.1 2488892.7 232921.3 2489090,9 233087.0 2489435.6 233125,6 2489513.8 233160,7 2489585.6 233201.2 2489666.2 233228,8 2489723.2 233239.3 2489745.1 Page 4 12/12/95 CLOSURE DL/ DISTNCE AZIMUTH 100 2293,4 352.38 0.63 2331.7 352.77 0.28 2369,7 353.14 0.61 2406.8 353.47 1.00 2442.7 353.79 0.73 2477.8 354.09 0.33 2512.6 354,38 0.41 2546.7 354,67 0.50 2580.0 354,95 0.66 2612.3 355.23 0.71 2643,9 355.50 0.44 2675.1 355.75 0.47 2705.6 356.02 0.71 2747.8 356.41 3.86 2786.6 356,75 5.97 2833.1 357.14 6.12 2886.9 357.57 6,42 2945.6 358.04 4.80 2998.9 358.47 2.98 3197,8 359.95 0.72 3549.6 2.51 0.56 3630,3 3,03 1.73 3704.7 3.49 2,21, 3788.5 4.00 0.70 3847.9 4.33 2.07 3870.7 4.45 5,61 0 ,q 0 A4 iA- 11 LN MEAS DEPTH INCLN DIRECTION ANGLE AZ IMUTH 9625 51 . 80 26 . 80 9645 51.80 29.60 9738 52.60 27.50 9998 52,30 28,90 10124 51.10 28.20 )i0207 50.40 28,20 10290 47.70 21.90 10385 45.30 1]..40 10508 41,00 0.10 10560 39.00 348.80 VERT I CAL- DE PTHS TVD SUB-SEA 8446.3 8330.3 8458.6 8342.6 8515.6 8399.6 8674.1 8558.1 8752.2 8636.2 8804,7 8688.7 8859.1 8743.1 8924.6 8808,6 90].4.5 8898,5 9054.3 8938.3 3 10597 38.50 346.10 9083.2 8967.2 3 10627 39.20 343.90 9106.6 8990.6 3 10650 39.60 342.50 9124.3 9008.3 3 10772 42.50 343.90 9216.3 9100.3 3 10808 43.20 349.60 9242,7 9126.7 3 10854 43.20 348.80 3 10885 44.30 355.90 3 10924 45.10 358.00 3 10979 50.20 6.40 .i11008 51.60 6.40 9276.3 9160.3 9298.7 9182.7 9326.4 9210.4 9363.5 9247.5 9381.8 9265.8 SECTION DEPART RECORD OF SURVEY COORDINATES-FROM ALASKA Zone 4 Wellhead X Y DISTNCE 3939.8 3925.7 N 333.2 E 3954.3 3939.6 N 340.6 E 4021.7 4004.1 N 375.7 E 4211.2 4185.8 N 473.1 E 4301.9 4272.7 N 520,4 E 4360,9 4329.3 N 550.8 E 4419.8 4386.0 N 577.3 E 4487.1 4451,8 N 597.2 E 4570.9 4535.2 N 605,9 E 4603.6 4568.3 N 602.7 E 4625.7 4643.4 4656,9 4731.3 4754.5 4784.8 4805.7 4832.8 4873.4 4895.9 3 11056 51.20 7.80 9411.7 9295.7 4933.3 3 11137 51.40 7.10 9462.4 . 9346.4 4996.5 3 11254 50.80 8.50 9535.8 9419.8 5087.5 3 11371 51.20 10.60 9609.5 9493,5 5178.1 3 11486 50.00 9.90 9682.5 9566.5 5266.6 3 11571 49,00 2.90 3/MWD 9737.7 9621.7 ,, 4590.9 N 597.7 E 4609,1 N 592,8 E 4623,,1 N 588.6 E 4699.8 N 565.5 E 4723,6 N 559.9 E ^Station Types: lAnadrill (c)95 A41AllD2 2.5b.04 8:35 AM D) 4754.5 N 554.0 E 4775.7 N 551.2 E 4803,1. N 549.7 E 4843.7 N 551.4 E 4866.0 N 553.9 E 4903.2 N 558.5 E 4965.9 N 566.7 E 5056.1 N 579.1 E 5145.8 N 594.2 E 5233.2 N 610.0 E 5331.1 5297.4 N 617.2 E Page 5 12/12/95 CLOSURE AZIMUTH 233273,5 2489811.0 3939.9 233281,2 2489824.7 3954.3 233317.8 2489888,4 4021.7 233419.3 2490067,8 4212.5 233468.6 2490153.6 4304.2 233500.2 2490209.5 4364.2 233528.1 2490265.6 4423.8 233549.4 2490330.9 4491,7 233560.0 2490414.0 4575.5 233557.6 2490447,3 4607.9 233553.1 2490470.0 4629.7 233548.6 2490488.3 4647,1 233544.7 2490502.3 4660.4 233523.4 2490579.5 4733.7 233518.3 2490603.5 4756.6 233513,1 2490634.5 233510.8 2490655.8 233509,9 2490683,2 233512,5 2490723.7 233515.5 2490746.0 233521.0 2490783.1 233530.6 2490845,6 233545.1 2490935.5 233562.2 2491024.8 233580.0 2491111.8 233588.7 2491175.8 DL/ 100 4,85 1.37 4.94 11.00 5.36 1.98 6.45 0.44 6.94 1.05 7.25 0.84 7.50 6.59 7.64 8,40 7.61 7,18 7.52 14.47 7.42 4.76 7.33 5.16 7.26 4.24 6.86 2.49 6.76 10.94 4786.7 4807.4 4834.5 4874.9 4897.4 6.65 1,19 6.58 16.22 6.53 4,31 6.49 14,59 6.49 4.83 4934.9 4998.2 5089.2 5180.0 5268.7 6,50 2.43 6.51 0.72 6 . 53 1.06 6.59 1.44 6.65 1.14 5333.2 6.65 6.37 A41A-11LN RECORD OF SURVEY Page 6 12/12/95 S MEAS INCLN DIRECTION VERTICAL-DEPTHS SECTION COORDINATES-FROM ALASKA Zone 4 T DEPTH ANGLE AZIMUTH TVD SUB-SEA DEPART Wellhead X Y 3 11612 49.80 357.30 9764.4 9648.4 5362.1 5328.5 N 617.2 E 233589.4 2491206.9 5364.1 J 12047 49.80 357.30 10045.2 9929.2 5691.3 5660~4 N 601.6 E 233581.3 2491539.0 5692.3 Final closure from wellhead: 5692.3 FEET at 6.07 t" :ation Types: 3/MWID J/PROJECTED CLOSURE DL/ DISTNCE AZIMUTH 100 6 . 61 10.55 6.07 o.oo ~ , (Anadrili (c}95 A4]AllD2 ~..5b.04 8:'35 AM 13) Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 12/12/95 'Client .... : SHELL WESTERN E & P INC Field ..... : MIDDLE GROUND SHOAL, A-PLATFORM Well ...... : A41A-11LN Vert sect.: 5.04 deg az DD engnr..: Gary Paul Units ..... : FEET )lhead coordinates...: 0,0 Position calc.: Minimum Curvature Dogleg calc...: Lubinski Survey Date...: 12/12/95 KB Elevation..: 116.00 ft Reference ..... : AFE#739930/Job#36543 Magnetic dcln,: +22.598 (E) RECORD OF StTRVEY Pg: 1 MEAS INCI,N DIRECTION DEPTH ANGLE AZIMI.~H ~_~:~ .............. 0 0.00 0.00 42 1.05 221.00 100 0.37 269.00 200 0.52 291.00 300 0.53 306.00 VERTICAL-DEPTHS SECTION TVD SUB- SEA DE PART 0 . 0 -116 . 0 0 . 0 42 . 0 -74 . 0 -0 . 3 100 . 0 - 16 . 0 - 0 . 8 200.0 84.0 -0.7 300 . 0 184 . 0 -0 . 3 COORD I NATES - FROM Wellhead 0.0 N 0.0 E 0.3 S 0.3 W 0.7 S 0.8 W 0.5 S 1.5 W 0.1 S 2.3 W A3~ASKA Zone 4 X Y 232851.0 2485893.9 232850.7 2485893.7 232850.1 2485893.3 232849.4 2485893.4 232848.6 2485893.9 CLOSURE DL/ DISTNCE AZIMUTH 100 0.0 0.00 0.00 0.4 221.00 2,50 1.0 228.55 1.46 1.6 .250.57 0.22 2.3 267.45 0.14 400 0.60 273.00 500 0.78 263.00 600 0.78 269.00 700 2.48 332.00 800 5.02 357.00 400.0 284.0 -0.1 500.0 384.0 -0.2 600.0 484.0 --0.5 699.9 583.9 1.3 799.7 683.7 '7.4 0.2 N 3.2 W 0.1 N 4,4 W 0.0 N 5.8 W 1.9 N 7.5 W 8.2 N 8.7 W 232847.7 2485894.2 232846.5 2485894.2 232845.2 2485894.1 232843.5 2485896.1 232842.4 2485902.4 3.2 273.50 0.33 4.4 271.83 0.22 5.8 270.46 0.08 7.7 284.58 2.24 12.0 313.29 2.96 7 900 7.57 3.00 7 1000 10.50 7.00 7 1100 12.82 5.00 7 1200 14.48 1.00 ^Station T}~es: 7/GYRO 899.1 783.1 18.3 19.2 N 8.6 W 997.9 881.9 34.0 34.8 N 7.2 W 1095.8 979.8 54.2 54.9 N 5.1 W 1193.0 1077.0 77.8 78.4 N 3.9 W 232842.8 2485913.3 232844.6 2485928.9 232847.1 2485948.9 232848.8 2485972.5 21.0 335.79 2.63 35.5 348.37 3.00 55.1 354.71 2.35 78.5 357.15 1.91 (Anadrill ',c)95 A41AllD2 2.5b.04 B:35 AM D) ORIGINAL © O O A41A-11LN S MEAS INCLN DIRECTION T DEPTH ANGLE AZIMUTH -. '7 1300 15.42 353 .00 7 1400 16 . 90 346 . 00 7 1500 19.52 344 . 00 7 1600 20.72 345.00 7 1700 21.78 345.00 '/ 1800 23.12 346.00 7 1900 23.58 346.00 7 2000 23.47 345.00 7 2100 24. 18 345.00 7 2200 25.08 345.00 VERTICAL--DEPTHS SECTION TVD SUB-SEA DEPART 1289.6 1173.6 103.3 1385.6 1269.6 130.0 1480.6 1364.6 159.4 1574.5 1458.5 191.6 1667.7 1551.7 225.6 1760.1 1644.1 1851.9 1735.9 1943.6 1827.6 2035,1 19].9.1 2126.0 2010.0 7 2300 25.42 345.00 7 2400 24.93 344.00 7 2500 24.68 344.00 7 2600 24.62 344.00 7 2700 24.30 343.00 2216.5 2100.5 2307.0 2191.0 2397.7 2281.7 2488.6 2372.6 2579.6 2463.6 2800 23.98 343.00 2900 23.73 342.00 3000 23.50 342.00 3100 23.20 341.00 3200 23,52 342.00 2670.9 2554.9 2'762 . 4 2646 . 4 2854.0 2738.0 2945 . 8 2829.8 3037.6 2921.6 7 3300 23.70 342.00 7 3400 23.65 342.00 7 3500 23.48 344.00 7 3600 23.93 342.00 7 3700 24,92 343.00 3800 .... '~Station 26.05 344.00 Types: 7/GYRO 3129.2 3013.2 3220.8 3104.8 3312.5 3196.5 3404.0 3288.0 3495.1 3379.1 3585.3 3469.3 ,.. (Anadrill (c)95 A41AllD2 2.5b.04 8:35 AM D) RECORD OF SURVEY COORDINATES-FROM ALASKA Zone 4 Wellhead X Y 104.1 N 5.3 W 131.4 N 10.4 W 16]..6 N 18.6 W 194.8 N 27.7 W 229.8 N 37.1 W 261.6 266.7 N 46.7 W 299.1 305.2 N 56.3 W 336.7 343.8 N 66.3 W 374.6 382.8 N 76.7 W 413.8 423.1 N 87.5 W 453.9 464.3 N 98.5 W 493.7 505.3 N 109.9 W 532.9 545.6 N 121.5 W 571.8 585.7 N 133.0 W 610.3 625.4 N 144.7 W 648.2 664.5 N 156,7 W 685.6 703.1 N 168.8 W 722.4 741.2 N 181.2 W 758.8 778.8 N 193.8 W 795.1 816.4 N 206.4 W 832.0 854.5 N 218,7 W 868.9 892.7 N 231,2 W 906.0 930.9 N 242.8 W 943.2 969.3 N 254.6 W 981.4 1008.8 N 267.0 W 1021.4 1050.0 N 279.2 W 232848.0 2485998.2 232843.5 2486025.6 232836.1 2486055.9 232827.7 2486089.3 232819.1 2486124.5 232810.4 2486161.7 232801.7 2486200.3 232792.5 2486239.2 232783.0 2486278.4 232773.1 2486318.9 232763.0 2486360.4 232752.6 2486401.6 232741.9 2486442.2 232731.4 2486482.5 232720.5 2486522.5 232709.5 2486561.9 232698.2 2486600,7 232686.7 2486639.1 232675.0 2486676.9 232663.2 2486714.8 232651.7 2486753.2 232640.2 2486791.6 232629.4 2486830.1 232618.5 2486868,,8 232607.0 2486908.5 232595.7 2486950.1 Page 2 12/12/95 CLOSURE DL/ DISTNCE AZIMITEH 100 104.3 357.09 2,26 131.9 355.46 2.45 162.7 353.45 2.69 196.7 351.89 1.25 232.7 350.82 1.07 270.8 350.07 1.39 310.3 349.55 0.47 350.2 349.09 0.42 390.5 348.67 0.72 432.1 348.32 0.90 474.7 348.02 0.33 517.1 347.73 0.64 559.0 347.45 0.25 600.6 347.21 0.07 642.0 346.97 0.52 682.8 346.73 0.32 723.1 346.50 0.48 763.0 346,26 0.23 802.5 346.03 0.50 842.1 345.81 0.51 882.0 345,64 922.1 345.48 962.1 345,38 1002.2 345,28 1043.5 345.17 1086.5 345.11 0.18 0.05 0.82 0.92 1.07 1.21 / / A41A-11LN S MEAS INCLN DIRECTION 'T DEPTH ANGLE AZIMI3TH 7 3900 27.17 343,00 7 4000 28.35 343.00 7 4100 29.22 343.00 7 4200 29.78 343.00 7 4300 28.92 342.00 }4400 28.97 7 4500 29.53 7 4600 30.20 7 4700 27.92 7 4800 26.70 VERTICAL-DEPTHS SECTION TVD SUB-SEA DEPART 3674.8 3558.8 1063.1 3763.2 3647.2 1106.3 3850.9 3734,9 ].150.9 3937.9 3821.9 1196.5 4025.1 3909,1 1241.8 343.00 4112.6 3996.6 343.00 4199.9 4083.9 344.00 4286.6 4170.6 349.00 4374.0 4258.0 357.00 4462.9 4346.9 7 4900 27.93 7 5000 29.18 7 5100 29.42 7 5200 29.73 7 5300 29.32 359.00 4551.7 4435.7 359,00 4639.6 4523.6 359.00 4726.8 4610~8 358.00 4813.7 4697.7 359.00 4900.7 4784.7 7 5400 29.1,2 7 5500 29.07 7 5600 28.23 7 5700 26.68 ]5800 25.13 / 7 5900 25.85 7 6000 26.22 7 6100 25.55 7 6200 25.02 7 6300 24.52 RECORD OF SURVEY 7 6400 25.08 ~Station Types: COORDINATES-FROM Wellhead 7/GYRO 1093.0 N 292.0 W 1137.5 N 305.6 W 1183.6 N 319,7 W 1230.7 N 334.1 W 1277.4 N 348.8 W 1286.5 1323.5 N 363.3 W 1331.8 1370,3 N 377.6 W 1378.1 1418.0 N 391.8 W 1424.1. 1465.2 N 403.2 W 1468.9 1510.6 N 408.8 W 1514.4 1556.5 N 410.4 W 1561.9 1604,3 N 411.2 W 1610.6 ].653.2 N 412.1 W 1659,6 1702.5 N 413.4 W 1708.6 1751.8 N 414.7 W 4.00 4988.0 4872.0 1757.3 1.800.6 N 413.4 W 10.00 5075.4 4959.4 1805.8 1848.8 N 407.5 W 12.00 5163,2 5047.2 1853.5 1895,8 N 398.4 W 13.00 5251.9 5135.9 1899.2 1940.8 N 388.4 W 14.00 5341.9 5225.9 1942.4 1983.3 N 378.2 W 13,00 5432,1 5316.1 1985.0 2025.2 N 368,2 W 1.4.00 5522.0 5406.0 2028.4 2067.9 N 357.9 W 14.00 5612.0 5496.0 2071.5 2110.2 N 347.3 W 14.00 5702.4 5586.4 2113.7 2151.7 N 337.0 W 15.00 5793.2 5677.2 2155.0 2192.2 N 326.5 W 16.00 (Anadrill (c)95 A41AllD2 2.9b.04 8:35 AM D) 5884.0 5768.0 2196.3 2232.6 N 315.3 W ,. ALASKA Zone 4 X Y 232584.0 2486993.3 232571.4 2487038.1 232558.32487084.5 232545.0 2487131.9 232531.4 2487178.9 232517.9 2487225.4 232504.6 2487272.4 232491.6 2487320,5 232481.3 2487367.9 232476.7 2487413.5 Page 3 12/12/95 CLOSURE DL/ DISTNCE AZIMUTH 100 1131,3 345.04 1.20 1177.9 344.96 1.18 1226.0 344.89 0.87 1275.2 344.81 0.57 1324.2 344.73 1,00 1372.5 344.65 0.49 1421.4 344,59 0.57 1471.1 344.56 0.83 1519.7 344.61 3.33 1565.0 344,86 3.86 232476.1 2487459.3 1609.7 232476.4 2487507.2 1656.1 232476.6 2487556.1 1703.8 232476.5 2487605.4 1752.0 232476.3 2487654.7 1800.2 232478.7 2487703.4 232485.7 2487751.5 232495.9 2487798.3 232506.9 2487843.1 232518.0 2487885,3 232529.0 2487927.0 232540.3 2487969.4 232551.8 2488011.5 232563.0 2488052.7 232574.5 2488093.0 232586.6 2488133.1 345.23 1.54 345.62 1.25 346.00 0.23 346.35 0.59 346.68 0.65 1847.4 347.07 2.45 1893,1 347.57 2.92 1937.2 348.13 1.27 19'79.3 348.68 1.62 2019.1 349.20 1.61 2058.4 349.70 0.84 2098.6 350.18 0.57 2138.6 350.65 0.67 2177.9 351.10 0.53 2216.4 351.53 0.65 2254.8 351.96 0.71 0 A41A- llLN S MEAS INCLN DIRECTION T DEPTH ANGLE AZIMI3TH 7 6500 24.62 15.00 7 6600 24.33 15.00 7 6700 23.88 14.00 7 6800 22.88 14.00 7 6900 22.15 14.00 , 7000 21.82 14.00 7 7100 21.63 15.00 7 7200 21.13 15.00 7 7300 20.58 16.00 7 7400 19.97 17.00 VERTICAL-DEPTHS SECTION TVD SUB-SEA DEPART 5974.7 5858.7 2237.6 6065.7 5949.7 2278.4 6157.0 6041.0 2318.7 6248.8 6132.8 2357.9 6341.2 6225.2 2395.7 6433.9 6317.9 2432.7 6526.8 6410.8 2469~2 6619.9 6503.9 2505.1 6713.3 6597.3 2540.2 6807.2 6691.2 2574.1 7 7500 19.68 16.00 6901.2 6785.2 7 7600 19,35 17.00 6995.5 6879.5 3 7700 19.08 19.00 7089.9 6973.9 3 7826 23.90 20.90 7207.1 7091.1 3 7920 29.40 18.40 7291.1 7175.1 3 8014 35.10 19.80 7370.6 7254.6 3 8108 4]..10 18.70 7444,5 7328.5 3 8201 45.10 21.60 7512.4 7396,4 3~ 8281 47.10 19.80 '?567.9 7451.9 ~ 8573 4.7.50 22.60 7765.9 7649.9 3 9087 48.70 26 . 10 3 9202 49.90 24.00 3 9305 51 . 90 25 . 40 3 941_9 52 . 70 25 . 40 3 9499 52.00 23 . 50 8109.2 7993.2 8184.2 8068.2 8249.2 8133.2 8318.9 8202.9 8367,8 8251.8 9530 51.10 25.40 8387.1 8271.1 ~Station Types: 3/MWD 7/GYRO iAnadr[ll (c)95 A41AllD2 2.5b.04 8:35 AM D) RECORD OF SLTRVEY COORDINATES-FROM ALASKA Zone 4 Wellhead X Y 2273.1 N 304.1 W 2313.1 N 293.4 W 2352.7 N 283.1 W 2391.2 N 273.5 W 2428.3 N 264.3 W 232598.7 2488173.4 232610.4 2488213.1 232621.5 2488252.4 232632.0 2488290.7 232642.1 2488327.6 2464.7 N 255.2 W 2500.5 N 245.9 W 2535.7 N 236.5 W 2570.0 N 227.0 W 2603.3 N 217.2 W 232652.0 2488363.7 232662.0 2488399.4 232672.3 2488434.4 232682.6 2488468.4 232693.2 2488501.4 2607.4 2640.1 2672.2 2716.7 2757. 5 2635.8 N 207.5 W 266'7.8 N 198.0 W 2699.1 N 187.9 W 2742.4 N 172,1 W 2782.2 N 158.0 W 232703.5 2488533.7 232713.7 2488565.5 232724.6 2488596.6 232741,4 2488639.6 232756.4 2488678.9 2806.1 2829.5 N 2862.4 2884.3 N 2923.7 2943.9 N 2979.2 2997.8 N 3185.2 3197.8 N 141.5 W 232773.9 2488725.9 122.4 W 232794,3 2488780.2 100.5 W 232817.5 2488839.3 80.1 W 232839.1 2488892.7 2.5 W 232921.3 2489090.9 3546.1 3546.2 N 155.3 E 3628.1 3625.2 N 192.1 E 3703.3 3697.8 N 225.6 E 3787.9 3779.3 N 264,2 E 3847.6 3836.9 N 290.5 E 233087.0 2489435.6 233125.6 2489513.8 233160.7 2489585.6 233201.2 2489666.2 233228.8 2489723.2 3870.5 3859,0 N 300.5 E 233239.3 2489745.1 Page 4 12/12/95 CLOSURE DL/ DISTNCE AZIMUTH 100 2293.4 352.38 0.63 2331.7 352.77 0.28 2369.7 353.14 0.61 2406.8 353.47 1.00 2442.7 353.79 0.73 2477.8 354.09 0.33 2512.6 354.38 0.41 2546.7 354.67 0.50 2580.0 354.95 0.66 2612.3 355.23 0.71 2643.9 355.50 0.44 2675.1 355.75 0.47 2705.6 356.02 0.71 2747.8 356.41 3.86 2786.6 356.75 5.97 2833.1 357.14 6.12 2886.9 357.57 6.42 2945.6 358,04 4.80 2998.9 358.47 2.98 3197.8 359.95 0.72 3549.6 2.51 0.56 3630.3 3.03 1.73 3704.7 3.49 2.21. 3788.5 4.00 0.70 3847.9 4.33 2.07 3870.7 4.45 5.61 O O / / / A41A-11LN 3 3 3 3 3 MEAS DEPTH INCLN DIRECTION ANGLE AZIMUTH 9625 51 . 80 26.80 9645 51.80 29.60 9738 52,60 27.50 9998 52.30 28.90 10124 51.10 28.20 ,~0207 50.40 28.20 10290 47.70 21.90 10385 45.30 1]..40 10508 41.00 0.10 10560 39.00 348.80 3 1059'7 38.50 346.10 3 10627 39.20 343.90 3 10650 39.60 342.50 3 10772 42.50 343.90 3 10808 43.20 349.60 3 10854 43.20 348.80 3 10885 44.30 355.90 3 10924 45.10 358,00 3 10979 50.20 6.40 il].008 51.60 6.40 3 11056 51.20 7.80 3 11137 51.40 7.10 3 11254 50.80 8.50 3 11371 51.20 10.60 3 11486 50,00 9.90 VERTICAL-DEPTHS TVD SUB-SEA 8446.3 8330.3 8458.6 8342.6 8515.6 8399.6 8674.1 8558.1 8752.2 8636.2 8804.7 8688,7 8859.1 8743.1 8924.6 8808.6 9014,5 8898.5 9054.3 8938.3 9083,2 8967.2 9106.6 8990.6 9124.3 9008.3 9216.3 9100.3 9242,7 9126,7 9276.3 9160.3 9298.7 9182.7 9326.4 9210.4 9363.5 9247.5 9381.8 9265.8 9411.7 9295.7 9462.4, 9346.4 9535.8 9419.8 9609.5 9493.5 9682.5 9566.5 3 11571 49.00 2.90 ^Station Types: 9737.7 9621.7 ,. (Anadrill (c)95 A41AllD2 2.5b.04 8:35 AM D) SECTION DEPART RECORD OF SURVEY COORDINATES-FROM Wellhead 3939.8 3925.7 N 333.2 E 3954.3 3939.6 N 340.6 E 4021.7 4004,1 N 375.7 E 4211.2 4185,8 N 473.1 E 4301,9 4272.7 N 520.4 E 4360.9 4329.3 N 550.8 E 4419.8 4386.0 N 577.3 E 4487.1 4451,8 N 597.2 E 4570,9 4535.2 N 605.9 E 4603.6 4568.3 N 602.7 E 4625.7 4590.9 N 597.7 E 4643.4 4609.1 N 592.8 E 4656.9 4623.1 N 588.6 E 4731.3 4699.8 N 565.5 E 4754.5 4723.6 N 559.9 E 4784.8 4754.5 N 554.0 E 4805.7 4775.7 N 551.2 E 4832.8 4803.1. N 549.7 E 4873.4 4843.7 N 551.4 E 4895.9 4866.0 N 553.9 E 4933.3 4903.2 N 558.5 E 4996,5 4965.9 N 566.7 E 5087.5 5056,1 N 579.1 E 5178.1 5145.8 N 594.2 E 5266.6 5233,2 N 610.0 E 5331.1 5297.4 N 617.2 E ALASKA Zone 4 X Y 233273.5 2489811.0 233281.2 2489824.7 233317.8 2489888.4 233419.3 2490067.8 233468.6 2490153.6 233500,2 2490209.5 233528.1 2490265.6 233549.4 2490330.9 233560.0 2490414.0 233557.6 2490447.3 233553.1 2490470.0 233548.6 2490488.3 233544.7 2490502.3 233523.4 2490579.5 233518.3 2490603,5 233513.1 2490634.5 233510.8 2490655.8 233509.9 2490683.2 233512.5 2490723.7 233515.5 2490746.0 233521.0 2490783.1 233530.6 2490845.6 233545.1 2490935.5 233562.2 2491024.8 233580.0 2491111.8 233588.7 2491175.8 Page 5 12/12/95 CLOSURE DL/ DISTNCE AZIMC3TH 100 3939.9 4.85 1.37 3954,3 4,94 11.00 4021,7 5.36 1.98 4212.5 6.45 0.44 4304.2 6.94 1,05 4364.2 7.25 0.84 4423.8 7.50 6.59 4491.7 7.64 8.40 4575.5 7.61 7.18 4607.9 7.52 14.47 4629.7 7.42 4.76 4647.1 7,33 5.16 4660.4 7.26 4.24 4733.7 6.86 2.49 4756.6 6.76 10.94 4786.7 6.65 1.19 4807.4 6.58 16.22 4834.5 6.53 4.31 4874.9 6.49 14.59 4897.4 6.49 4.83 4934.9 6.50 2.43 4998.2 6.51 0.72 5089.2 6.53 1.06 5180.0 6.59 1.44 5268.7 6.65 1.14 5333.2 6.65 6.37 A41A-11LN RECORD OF SURVEY S MEAS INCLN DIRECTION VERTICAL-DEPTHS SECTION COORDINATES-FROM ALASKA Zone 4 T DEPTH ANGLE AZIMUTH TVD SUB-SEA DEPART Wellhead X Y 3 11612 49.80 357.30 9764.4 9648.4 5362.1 5328.5 N 617.2 E 233589.4 2491206.9 - 5364.1 J 12047 49.80 357.30 10045.2 9929.2 5691.3 5660.4 N 601.6 E 233581.3 2491539.0 5692.3 Final closure from wellhead: 5692.3 FEET at 6.07 :ation Types: 3/MWD J/PROJECTED Page 6 12/12/95 CLOSURE DL/ DISTNCE AZIMTJTH 100 [] 0 6 . 61 10.55 6.07 0.00 --J ,_.l 0 (Anadril[ (c)95 A41AllD2 2.5b.04 8:35 AM D) ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 15, 1995 Mr. Alan Foglesong Senior Production Engineer Shell Western E&P Inc. 130 Trading Bay, Suite 310 Kenai, Alaska 99611 Re: No-Flow Verification MGS Well A-4 lA-11LN Dear Mr. Foglesong: On November 3, 1995 our Inspector, John Spaulding, witnessed a "no-floxv" test on Shell well MGS A - 4 lA-11LN (PTD 95-119). Gas hR had been shut off and the well depressured 16 hours before the inspector arrived. The well was shut in for 1 hour and then opened to the separator; no fluids were observed and the gas was too small to measure. The Inspector concluded that subject well was not capable of unassisted flow of hydrocarbons. MGS well A-41A-11LN (PTD 95-119) meets the criteria ora "no-flow" performance test and as such is considered incapable of flow to the surface. Under the authority of 20 AAC 25.265(A) it is not required to have a fail safe automatic SSSV, however, the pilot and surface safety valve must be maintained in good condition and, if for any reason, the well again becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be reinstalled and maintained in good working condition. Sincerely, Blair E. PI Supervisor cc: John Spaulding b~w/nf-m~s I w MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Joh~ DATE: Chairman ~ November 3, 1995 THRU: Blair Wondzell, P. I. Supervisor FILE NO: lv31kccd.doc FROM: John Spaulding,~-~ SUBJECT: Petroleum lnsp¢ ~ No Flow Test Shell Western E&P Platform "A" A41A-11LN Middle Ground Shoals Unit q$-- ire) Friday November 3, 1995: I traveled to Shell Western E&P Platform "A" to witness a No Flow test o~ well A41A-11LN. The tubing and inner annulus gas lift had been shut in and de-pressured 16 hours prior to my arrival. The tubing was then opened to a de-prssured separator with a fluid meter and sight guage to monitor fluid build up. There were also provisions made to monitor any gas flow through a 1/2" orfice plate and chart recorder. The well was shut in and positive pressure was recorded on a 0-600 psi guage, the inner annulus also showed positive pressure but not measurable. After leaving the well shut in for I hour and no preesure build up (PBU) the well was opened to the seperator and no fluids were observed, gas flow would not register on the chart recorder. The well was then shut in for another PBU this lasted for 4 hours with the same results. I reccomend that the AOGCC consider well A41A-11LN for No Flow status. Summary: I witnessed the successful No Flow test on Shell Platform "A". October 24, 1995 Shell Western E&P Inc. An affiliate of Sh~ Oil Company P. O. Box 576 Houston, TX 77001 Mr. Larry Grant Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: SUBJECT: FORMATION TOPS PICKS FOR THE SWEPI MGS A41-A11LN, MIDDLE GROUND SHOAL FIELD, KENAI BOROUGH, ALASKA Here is a list of fommtion tops encountered in the SWEPI MGS A41-A11LN (API# 50-733-20179-03), as required by the AOC~C. Please note that this well was drilled through the overturned limb of the Middle Groined Shoal anticline, so the second set of Hemlock formation tops were encountered in reverse order. A-41-A11LN (KB= 116') Approximate Formation Top MD TVD Subsea GR 7,900' 7,274' -7,158' GS 7,973' 7,337' -7,221' HC 8,350' 7,516' -7,500' HD 8,505' 7,721' -7,605' HE 8,580' 7,772' -7,656' HF 8,626' 7,802' -7,686' HI 8,750' 7,886' -7,770' HK 8,812' 7,927' -7,811' HN 9,039' 8,079' -7,963' HR 9,313' 8,257' -8,141' HR (repeated) 9,795' 8,553' -8,437' HZ 10,030' 8,697' -8,581' HZ (overturned) 10,527' 9,032' -8,916' HR 10,843' 9,271' -9,155' HN 11,130' 9,461' -9,345' Fault 11,400' 9,631' -9,515' HI 11,558' 9,732' -9,616' HY 11,697' 9,821' -9,705' HE (mudlog top) 11,750' 9,855' -9,739' HC (mudlog top) 11,950' 9,983' -9,867' TD 12,047' 10,046' -9,930' If you have any questions, I can be reached at (713) 544-2389. Very' truly yours, Mafia A. BalT. arini Senior Petrophysical Engineer Shell Western E&P Inc. An affiliate of Shell Oil Company 130 Trading Bay, Suite 310 Kenai, AK 99611 (907) 283-3096 October 4, 1995 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: SUBMISSION OF FORM 10-403 APPLICATION FOR SUNDRY APPROVAL TO PRODUCE WELL NO. A41A-11LN. Enclosed in triplicate is the Application for Sundry Approval, Form 10-403, to produce A4 IA- I 1LN for approximately 3 - 6 months whereupon we would file a 10-404 to cease production and begin injection. Operations are expected to begin October 24, 1995. If you have any questions, please don't hesitate to call me at (907) 283-2509. Thank you! Sincerely, Alan Foglesong Senior Production Engineer Enclosures CC~ OCT 0 9 1995 Alaska 0ii & Gas Cons. Commission Anchorage Platform "A" Well Files J. M. Winder, WCK 5237 Western Asset File Room - WCK 6220 Kenai Engineering Files - MGS "A41A-11LN" - Category 5.6120 Kenai Operations Files STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend After casing Repair well Change approved program Operation shutdown Re-enter suspended well Plugging Time extension Stimulate Pull tubing Variance Perforate Other X 2. Name of Operator Shell Western E&P Inc. 3. Address 130 Trading Bay, #310 Kenai, AK 99611 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface Platform "A", Leg2, Cond 12: 1677'FSL & 367'FEL, $11. TSN, R13W, SM 6. Datum elevation (DF or KB) 116' KB 7. Unit or Property name Middle Ground Shoal 8. Well number A4~,- 11LN feet At top of productive interval 8500'MD: 4820'FSL & 368'FEL, 511, T8N, R13W, SM At effective depth At total depth 12170'MD: 2174'FSL & 4907'FEL, 51, T8N, R13W, SM 9. Permit number 95-119 10. APl numar ~' 733-20179-03 11. Field/Pool Hiddle Ground Shoal 12. Present well condition summary Total depth: measured 7765 feet true vertical 7151 feet Plugs (measured) Effective depth: measured 7360 feet Junk (measured) true vertical 6770 feet Casing Length Size Cemented Structural Conductor 330' 20" Surface :[990' 13-3/8" 810 sx Intermediate Production 7765' 7" 824 sx Liner Perforation depth: measured 6084' - 7289' true vertical Measured depth 1990' 7765' True vertical depth 1934' 7151' = . OCT 0 9 1995 5597' - 6703' Atask~ 0ii & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) TLtb±ng & packer not yet set as well is dr±il-lng at 10,743'. Well is permitted as water injector. Request permission to produce for approximately 3 - 6 months at which point we Packers and SSSV (type and measured depth) will file a 10-404 to cease production and begin injection. 13. Pttachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation October 24, 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Service Suspended 17. I hereby certif~y that the for _ee_oJ~cl is true-and correct to the best of my knowledge. Signed ~ 0~4~..~: ~/¢~~ Title Sr. Production Engineer FOR COmmiSSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test __ Location clearance Mechanical Integrity Test __ Subsequent form required 10- ~/--'~/ /,/~ F-/'¢,~¢ 7~¢~7- ~ Origina! Signed Byd~ David W. Johnston Approved by order of the Commission ¢,mp~ oved Copy /urned ___~/O c~omrms,~oner [Approval N~.~,(4----' /"7 7 Date SdBMi¥ IN'T~II~LICATE Form 10-403 Rev 06/15/88 DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL No. A41A-11LN A41A-11LN is currently being drilled. The drilling permit for this well was approved with the intent that this well would be an injector. That is still our ultimate intent. However, we are submitting this Application for Sundry Approvals (10-403) to produce this well for a period of approximately 3-6 months prior to turning it into an injector. After completing the well, we will perform a no-flow test (based on expected reservoir pressures, the well should not flow). If the well does flow, we will install a storm choke in the "X" nipple (the "X" nipple will be run at approximately 300'). The storm choke will save us the time and expense of running a SSSV on a well that will ultimately be an injector. It will also eliminate the use of a control line which we prefer not to have on an injector because of mechanical integrity concerns. When we are ready to begin water injection on A41A-11LN, we will submit a Report of Sundry Operations (10-404) indicating that we are done producing the well. We will then proceed to turn the well into an injector by inserting dummy valves in the gas lift mandrels and by removing the storm choke (if in fact it was necessary to install one). Please note that the attached 10-403 contains the same information that was included in the drilling permit since drilling is still in progress. When filing the 10-404 mentioned in the preceding paragraph, packer depth, tubing depth, actual total depth, etc., Mil be included. (This same data will also be included when we file the Well Completion Report, Form 10-407, after the well has been drilled and completed.) ~t~ska Oil & Gas Cons. Commission Anchorage C:Xfiles\sundry\411 lprod.doc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David J_~, Chairmah-~-~- THRU' FROM' Field Blair Wondzell, P. i. Supervisor Lou Grimaldi,~'-,,~,. Petroleum In§pector DATE: FILE NO: SUBJECT: September 24, 1995 AV3JIXCD.DOC BOP test Shell Platform "A" Middle Ground Shoal A-q/A -~l u~ PTD #95-119 Sunday, September 24, 1995: I witnessed the weekly BOP test on Shell Platform "A". The rig was ready to test when ! arrived and went quite well. George Brewster (Inlet Drilling Tooipusher) conducted a thorough check of all BOP components which revealed no failures. Although this rig is using a Diesel based mud, I could not smell excessive fumes and found the rig and platform to be very clean and neat. The gas detection system was tested and I was shown the records of the previous tests. SUMMARY: i witnessed the weekly BOP test on Shell Platform "A" .Test time 4 hours, No failures. Attachments' AV3JIXCD.XLS CC: STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Inlet drilling Ak. Inc. Operator: Shell Western Well Name: A-52 ,,~ /--//,~' - !/&/V Casing Size: 7" Set @ Test: Initial Weekly Rig No. A PTD # 95-119 Rep.: Rick Seltz DATE: Rig Ph.# 9/24/95 776-5241 Rig Rep.: George Brewster 7765 Location: Sec. 11 T. 8N R. 13W Meridian Seward X Other TEST DATA MISC. INSPECTIONS: Location Gen.: OK · Housekeeping: OK (Gen) Reserve Pit: N/A Standing Orders: OK P.T.D.: OK BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign OK Drl. Rig OK Hazard Section OK Quan. 1 Test Pressure P/F 250/3500 P 1 250/5000 25O/5OOO 1 250/5000 P 1 250/5000 P 2 250/5000 2 250/5000 N/Ai N/A P MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Gas Detectors P P H2S Detectors P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quart. Pressure P/F 1 250/5000 P 1 250/5000 P 1 250/5000 P I 250/5000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 13 250/5000 P 32 250/50O0 P 1 P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 4 Bottles 2500 Average 3,000 1,350 minutes 34 sec. minutes 22 sec. X Remote: x Psig. TEST RESULTS Number of Failures: 0 ,Test Time: 4.00 Hours. Number of valves tested 27 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow wit~ Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P, I. Supervisor at 279-1433 REMARKS: GOOD TEST! Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R. Orimaldi FI-021L (Rev. 2/93) AV3JIXCD.XLS TONY KNOWLE$, GOVERNOR ALAS~ OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 8, 1995 G. SNady, Manager Asset Administration Shell Western E&P Inc. P O Box 576 Houston, TX 77001-0576 Re: Well # Company Permit # Surf Loc Btmhole Loc Middle Ground Shoal A41A-11LN Shell Western E&P Inc. 95-119 1677'FSL, 367'EEL, Sec 11, T08N, R13W, SM 12170'MD, 2174'ESL, 4907'FEL, Sec 01, T08N, R13W, SM Dear Mr Nady: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. Chairman BY ORDER OF THE COMMISSION Ijb/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMMISSar.-,4 PERMIT TO DRILL 20 AAC 25.005 I a. Type of work Drill ~ Reddll F](-~ lb. Type of well. Exploratory [----I Stratigraphic Test l----1 Development Oil F--1 Re-Entry ~ Deepen r--'l Service[-x-~ Development Gas~---~ Single Zone[~ Multiple Zone[~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Shell Western E&P Inc. 116' KB feet 3. Address (WCK 5237) 6. Property Designation HIDDLE GROUND SHOAL P.O. Box 576, Houston, TX 77001-0576 ADL 18756 4. Location of well at surface PLATF A, LEG 2, COND 12 7. Unit or property Name 11. TypeBond(,~2o~c25.o~) 1677' FSL & 367' FEL Sll, T8N, R13W, S.H. MIDDLE GROUND SHOAL BLANKET At top of productive interval 8. Well number Number 8500' HD, 4820' FSL & 368' FEL Sll, T8N, R13W, S.H. A41A-11LN Amount00 HH 7522 At total depth 9. Approximate spud date 12,170' HD, 2174' FSL & 4907' FEL S1, T8N, R13~, S.H. $200,000 AUCUST 8, 1995 i 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 4497 feet 854 feet 3746 17o,170' THvDp feet ; I1~' 16. To be completed for deviated wells 17. Anticipated pressure (,, 2o ~c 25.035 (o × 2)) Kickoff depth 7765 feet Maximum hole angle 51 o ~imur, su,~:~ 928 ~g At total depth (TVD) 4603 18. Casin.g program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6' 5' 18~ Pl10 STL 6570' 5600' 5163' 12170'10,116' 800SX 19. To be completed forRedrill, Re-entry, and Deepen Operations R r -''~ D Present well condition summary ~- ' Total depth: measured 7765 feet Plugs (measured) true vertical 7151 feet AUG 0 1 1995 Effective depth measured 7360' feet Junk (measured) ,~iilSka 0ii & Gas Cons. Commission true vertical 6770 feet Anchorage Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 330' 20" Surface 1990' 13-3/8' 810 SX 1990' 1934' Intermediate Production 7765' 7' 824 SX 7765' 7151' Liner Perforation depth: measured 6084' - 7289' true vertical 5597' - 6703' 20. Attachments Filing fee [~] Property platF~-1 BOP Sketch m-~ Diverter Sketch ~-m Ddlling program ~m Drilling fluid program ~ Time vs depth plot F---) Refraction analysis ~] Seabed report J--) 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ,/Jt~ /%(G. S. NAD~itle MGR.-ASSET ADMIN. Date 7/31/95 Signed / ¢-- Comission Use Only Permit Number IApi numberI ¥//~[~:~ I Ap p.[.rov~ I..d ~)~t_e~ ISee cover letter ?.~'--/////~ I 50-~'~-.?_-7- ~- 42 / ? ?-O~' Ifor other requirements Conditions of ap~)roval Samples required ) I Yes I~41 No Mud Icg required I J Yes ~>~'l No Hydrogen sulfide measures~;~:~ Yes [~ No Directional survey required ~] Yes ~ No Requiredworkingpressure-forBOPE ~R2Mb~ 3M: ~-ISM-F-i'IOM-~ 15M Other: Original ed by order ofI_ Approved by David W. Johnston Commissioner the commission Date ~ Shell Western E&P Inc. An affiliate of Shell Oil Company P. O. Box 576 Houston, TX 77001 July 31, 1995 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: SUBJECT: SUBMISSION OF FORM 10-401 - APPLICATION FOR PERMIT TO DRILL MIDDLE GROUND SHOAL LATERAL HOLE WELL NO. A41A-11 LN FORM 10-403 - APPLICATION FOR SUNDRY APPROVAL TO ABANDON A41A-11 Enclosed, in triplicate, is the Application for Permit to Drill a lateral hole from Middle Ground Shoal Well No. A41A-11 (APl No. 20179-02). The lateral hole will be named A41A-11LN. Operations are scheduled to begin approximately August 8, 1995. Also enclosed is Form 10-403 Application for Sundry Approval to abandon the Tyonek perfs in Well No. A41A-11. If you have any questions or wish to discuss, please call Jeff Wahleithner at (713) 544-3344 or Bert Coxe at (713) 544-2235. Sincerely, · S. Nady anager - Asset Administration Western Asset Enclosures AUG 0 1 1995 Naska 0ii & Gas Cons. Commission ~chorage AK401 .DOC- I 08:39 FROM ANADRILL .L.I.. I_QQiA]'ION ?LA'T' ,IDDLE GROLJND '-3-1-.iAL FIELD A--I~LATF©RM COOK iNI_LET, AI.AE;KA WELL: A41A--11LN (pi ~' SU R FAC:E iLOCA l ION 1677 F'SL: 567 FEL S'1 I TO~N. R!ZW SM K~F I 1,5' MSL 2 11 '11 ID I-~0! G %-'C 01 TOBIt' :R l:SV.V SEWARD M F. R.I:'.) lAN · A24-01LW~.t 1 2 C-.- j:.- 12'G · : -~ A2:3-1'2(; A1 3~- 1 2ROG 1 t A1 1, 3R1G ' /// : / o i ... 2-]~S ~ A3~.- i4R2C 12 1 D TOTAL P.05 MIDDLE GROUND SHOAL WELL NO. A41A-11LN WELL PROGP, AM Middle Ground Shoal (MGS) A41A-11LN will be a deepening of existing well A41A-11. The objective is to install an injector in the West flank Hemlock reservoir. The well will be drilled directional out of the bottom of the existing 7" casing through the Hemlock to a TVD of 10,116'. The well will be completed with a 5" cemented liner across the Hemlock reservoir. The existing perforations in the 7" casing will be abandoned by cementing the 5" liner from TD to 400' above the top perforation. The Hemlock will be perforated, and the well completed as an injector. WELL: LOCATION: OBJECTIVE: EVALUATION A41A-11LN PLATFORM A, LEG 2, CONDUCTOR 12 1,677'FSL 367'FEL Sll TOBN R13W SM HEMLOCK GEOLOGY DRILLING PROGNOSIS FIELD: KB: MIDDLE GROUND SHOAL 116' DRILLING LOGS I WIRELINE LOGS AMS GR CAL LDT DITE CNL MUD SIGNIFICANT LOGGERS FORMATIONS G SANDS HEMLOCK HC HEMLOCK HR HEMLOCK HR2 HEMLOCK HC2 TD III II '1 I I MD HOLE MUD (TVD) S I ZE CAS I NG PROGRAM 330' 1,990' (1,934') 5,600' (5,163') 7,765' (7,151') 8,500' (7,710') 10,486' (9,035') 12,170' (10,116') III L 6II DIRECTIONAL PROGRAM 20" I 13 3/8" 7,1 AUG 0 1 1995 Alaska (J~l & Gas Cons. Comn]~[o. rl Anchorage 5II CEMENTED OIL BASE BUILD & MUD TURN TO 48 DEG N24E EXPECTED MUD I WEIGHT I 9.6 PPG i i i BUILD & TURN TO 50 DEG NO5E MIDDLE GROUND SHOAL A41A-11LN DRILLING FLUID PROGRAM The 6" hole will be drilled using an oil base mud. The anticipated mud weight is 9.6 ppg. EXPECTED PRESSURES The maximum expected pressure gradient is 0.455 psi/ft. The maximum expected bottom hole pressure is 4,603 psi at 10,116'TVD. The expected maximum surface pressure with an oil fluid column and the well shut in is 928 psi. A 6" hole will be drilled out of the existing 7" casing to TD. 5" 18#/ft N80 flushjoint liner will be run to TD and hung at approximately 5,600'MD. The production liner will be cemented across the entire length and perforated in the Hemlock interval. · 11. 12. 13. DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL A41A-11LN 1. Move to A41A-11 (leg 2, conductor 12) and rig up. 2. Kill well. Test casing to 2,500 psi. 3. Nipple up 5,000 psi BOP stack and test. 4. Pull tubing strings and packer completion equipment. 5. Retrieve tubing conveyed perforating guns. 6. GIH with bit and drill out float shoe and 10' of formation. 7. Pressure test the shoe to an 10.5 ppg equivalent mud weight. 8. Directional drill to 12,170'MD-KB using a 6" hole. Final hole angle will be 50 degrees in a S05E direction. Log. Run a 5" production liner from TD at 12,170'MD-KB to 5,600'MD-KB. Cement liner. (Liner will be cemented above existing perforations.) Clean out cement and pressure test liner to 2,500 psi. Perforate. Run packer and tubing. (Packer at approximately 8,400'MD-KB.) Anadrill Schlumberger Alaska District 1111 East 80th Avenue ..... Aneh~raSe, 'aK '995~8 ' " '[90'7)"~49:4~1i ' F~x"349:2489 DIRECTIONAL WELL PLAN for SHELL WESTERN E. & P INC Well ......... : A41A-11LN(P01) vr~pared,,;.,:'O?/26/95 .Field ........ : NIDDLE GROUI~ $~OAL~ A-PLATFORM : Section &~,',.,; 5,04 Computation., i" MINIF[~M ~JRVATURE .............................................................................................. Units ........ : ~T Mag~iC .D~[ 22,000 E ': ...... Scale Fac~or;~'".O,99998~'~ ........... -: -~r. face-Lat.,.o.: 60,~9592~60 N -% - . . Surface Lot~3.: 151.49551186 W ~OCATIONS - ALAS~ Zone: 4 Legal Description X-Coord Y-CoOrd Sur£a¢e ...... :.1677 FSL ..367 F~L .~11 T08N R13W SM.- 232850,95-248S893.95 -. Tie-in/KOP.,,: 4376 FSL 554 FEL Sll T08N R13W SM 232724.62 2488S96.58 Target,..,,..: 892 FSL 5045 FEL S01 T08N R13W SM 2335S3.20 2490374,03 BHL .......... : 2174 FSL 49~7 FEL $01 T08N R13W SM 233720.37 2491652,53 PROPOSED W1/LL PROFILE ANADRILL .. . "'AKA-DPC ' FEASI B'I L ITY :' P-LAI'q.' · . NOT APPROVED FOR EXECUTION · PLAN '1 --,3 I -n o · 8000 34.83 8100 41.81 8190 -48.12 10487 48.12 10487 48,12 .. 22.65 7361 7245 . 2793 23.40 7439 7323 2852 2-3.-91 - -7503 738-7 2-913 23,91 --9036 8920" 4530' 23.91" 9036 8920 4530' ..... 2672 2699,11 N 18~,87 W 232724.62 24885~.~.8 .'..' L$ <TIE 2691 2717,38 N' 181,58 W 232~31.33 24~6~-~..'?~. LS 0.97 2692 2718.88 N. ze$.o-7 W 23-2'?.32',8~ ~8~'i~';~0 .... ?R 0.97- .270~...27~9.~9~..N ....... ~7~.~4..~._~.7~..~..~f~.~.!~ .......... 7R...~,~.~ 2744 2766,51. N 162,47 W 232751.60 248866~J39' 5R 7.00 { · ' ............. :.<',i.".-.::::';. - _: - " 2816.64 N 14~.85 W 232792,31 24.88713';06'. 4R 7.00 · . 2873,65 N 118.59 ~ 232797.86 2488763,50 .3R- 7.00 29~2,06 N 92'.99 W 23282'4,79'2.48~;'~i"-" ' 7,00 44.95.00. ~ 6O.0,.O0 E 233553.20'249037'~';0~:".:-$8L 0,00 . ~95.0! .N 600.,.00 g 233553.2.0.2t90~74,.~4. 88~ 7.00 · . 10500 48,16 22.65 9045 8929 4540 4504,19 N 603,95 E 233557,36 249038)'~.!~.. 896 7.00 10600 48.92 13.36 9111 8995 4613 4'57'5.33 N 627,04 E 233582 06-2490453:1.72" 8-1L 7.00 m~D 7/Z00 C~VS...' -~06.93:-:-.~-:5'0~2~.-."' .---:..5..-04 .... :-SZ-7-~-'.'-:.-.9063 .... :?4~.~.~.:':....:46.4~.'~.?:9..N:::~...i.s.~~:~.z~.~.4~<~3u.:~?~.~{~.~i.~.:.i~?:..:.:v:.;..~:d.....;-'' 'TARGET #2[ .......... i2i~0"" 5'0.27 .... 5,04 ..... 10116 10000 ..... 5819"' 5777'00 N"'-738,'00 ~'-' 233720".37'"2491658~1--: ........... 0'.'00 ..................................................................................................................................................... a.~.- ?--~ ............................... · · -. . : · . . · {h~ad:il (e)~5 41AI~L 81,52 2:48 PM 1} ' ' ' .. - .·...'-. .. ~n ?/1oo. cu~w TARGET #1 cuRw. 7/~oo TIE- IN BURVSY -TOm OF WINDOW Roe/ctrav~ 7/.zoo 7700 z~.oe 1~.00 7090 6~74 7760 10.50 ~.00 7147 703~ 77~s ~.a.,~ ...... 1~.oo. · .715~. 7.o~s- 70oo ~o.ee ~?...ea ...... 7z~ .... 7.gfe. . . STATION MEAS INCLN DIRECTION VERT-DEPT~$ SECT RE~ATIVH-COORDINATES STAT~-PLANE.. '.. 'TOOL Db/ IDENTIFICATION DEPTH ANGLE AZIMUTH BKB SUB-S DIST FROM-THE-WEL.LH. EAD X Y '-.j.[.. FACE 100 . _~=_]~.m==~ ----==---- _ ==~-- m~H ..... ~~mm'm~--~=~=~=== .... ~~-W~rl[~~ ..... ~ .... ~ .......... . ~-- --~ .... ~ --.~=~ .... ~~ .... ~=~..~ ...... : · · ii 08:39 FROM ANADRILL I U SHEL S'P INC i : TVD Scale. : I.. incr. =: 880 feet : ' : .. . Oep Scale' ! inch '800 feel:' :~ :: ~, ; Drawn J ' 07/26/95:' . 5800-- · ' : ~nadri/] Sc#]Umbergen ":': · ~ : Marker I~ntification 140 BKB ~CTN. ~00-- .- " \ ' ' ' Al TIE-I~ SURVEY 7700 70gO 2672 19,08 x I 81 TOP ~ WlNOON' .7760 7147 2591 C) KOP/Ct~RVE 7/100 7765 7151 26g~' I8. ~5 ' ~ ~ : .- O) EN07~SO0 C~v; 8t90 7503 ~t3' 4~.'~2 · ~ ' ;. FI CU~VEJ7/~O0 ': ' 10487 g03~ 4530 481 · : I Gl 6ND 7j~tO0 DJFt~ 10693 9171 ~B3 50~7 70~ [ .... ~ H) TAR~T ~ · t~$70 tort6 58Zg' , AN ADEtl I AKA .DPC ,.. ~00 ~00 ~400 ~80¢ 3~00 3800' ~000 4400 4~00 ~5~00 ~600 ~0 6~00 6800 7~00 Section Departure i . m m m ) m Shell Western E&P Inc. Platform "A" Solids Sand Trap Derrick Shakers Derrick Shakers 1 To Mutumps Control/Mud To Mud~umps To De~asser System Desiiter 1 6 Co,ne DegasserI To De~~sser Mixers SI-IELL WESTERN E&P INC. MIDDI..E GROUND SHOAL FIELD U' 5 KSI LINES C~IOSS 3' x 3' x 3' x 3' 5 CI1OSS 3' x 3' x 3' X 3' X 3' 5 KSI 3' 5 KSI GA1'E VALVE AD,JUSTABLE MANLJAL C~OKE - 3' 5 KSI flEMOTE OPERATED CHOKE - 2-9/ 16' IOKSI t]YDRAULIC ADJUSTABLE PfIESS(JRE GAGE 4' LINES M~ID/GAS SEPAIIATOR 6' I.INE PLATFORM "A" Ctl0KE MANIFOLD INLET~ (~"') I(~ MIll) i'll'; · VENTED A f CROWN SHELL MINIMUM BOP STACK REQUIREMENTS M~n. Mtn. No Item I.D. Nominal 1 Flowline 7" '-~--'Fill up Line "~":- 3 Drilling Nipple ' 4' A~nular lC'rev'enter ~ :'F~O single or one dual hydrualically - ' - operated rams ~ Drilling spool wilh"~" and 3" m~n' --- oullels .. 7 Gate Valve ..3 I/8" '8 Gate Valve Power Op,era'le'd ~ i/8 ...... ~ _ine Io cho~,e manifold ..... ~7,- ,, , 0 Gale Valve 2.1/16" II Check Valve 2.1/16" 3 C.a~ing Spool 14 Valves Gale 1,13/16" '~ .Compo.und Pre,s'ure Giu.~ C'onnector 6 Control pl.u,~'or va!ye ..,J3./!6,'" 17 Kill line to rig mud pump mani'i0id 2' ' I x'2" c,0,', "' 'NOTE: Add~l~on~,l U,..)ec~l~cllionl lOt A~f/G,~l S¢~,,~c~ ~rc 9wen ~n SI,t~ll Well Control M.~nu~l, Appendix 6 18 OPTIONAL Line lO toatls~d~ co~ect~on 2" Rotati,~g I)lowoul i~r~venler Gale valve powel operated 6" DRAWING & CHECK LIST 104A SHELL CLASS 5M SURFACE IN'STALLATIONS NORMAL AIR/GAS ' FOR AIR/GAS DRILLING CONFIGURATION A .... ANNUL.AR PREVENTER BLIND RAM PIPE RAM 6" HOLE 5000 PSI STACK TOP OF DERRICK FLOOR BOYrOM OF ROTARY BEAM FILL UP LINE !DRILL :~ FLOW LINE INIPPLE ' · ~. PREVENTER 5000 PS[ I ,, .J /-' RIG CELLAR FLOOR 13-5/8' 5000 PSI FLANGE BLIND FLkI4 5000 PSI] PIPE RAM 5000 PSI J k ~-5/8.. ~ooo p~ DroLL q ~SPOOL ~d 13-S/8' SOO0 PSI WELLfiF_kD ROOM FLOOR RISER k -- 13-5/8' 50OO PSI F-LANCE DSA F ~ 7 1/16' 5000 PSI FLANGE SPOOL ~ ,o, _ TO · i:. '.'..:; .": SHELL: WES I'EHN__E P I:NC : · . Al TIE-iN ~VEY · 77O0 ~ 26~ ~B~ ~ ' ~ ~.~ .~. ~o ~'~. ' '~ ' .~ :~ PLAN VI C) g~t~ 7/lOO. 77~ 2719 mJJj. ~ m O) ~ 7/1~~ : Bl~ ' ~ · 29~. :' ~ I. . " ' EJ T~T t~ t0487m~ ' '4 ~ '' . ; ' : ~ ~ m CLOSU~.:...:"5824 'feet [J ~VE~ 7/1007/100~ I04B7t0693 ' 44~4~ J: ~0m~8 . DEC~I~TION-:, ~ 22J000 :E . . T~I J2 l~I70 5777 738 SCALE...~.:...:..' ~ inch.- i) T 0 ~ ~ ~ ~ 70' mm 5777 7~' DflAWN: ) ':07/26/95' . ., .-;. .. , . . [ . · ~m mm m m i i i ii [ .~,. -.~ ' .j,~ . 6500 .... ' ..... I ' J ' I ' · ~ .:.I ' · : I .,. , . ' ' .. · ....... : ' ..... . ~ ~ ~r~pC. ,. .............. F:EAS' BILl FY F I~h ~. ,~~x/~ ~ ~C,~ · i.. '' I .E/(ECLjTION J 4~0 __'__ i I 4o~ , . .. ~ I ' : ,. I , - ' ' ~ ~ :', "i 3000 ·~8 1 . ~ ' , I I ,: i ~o ~ '', [: ;j , ~ , 1-. : .... : ~500 " ~ ' I' " 35~ 3000 ~50~ ~000 ~500 ~000 500 0 ~ ; ~000 ~500:. ~000 :~. <- ~[ST ' EAST -> . i i i i ] i i i · ..., STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Attercasi~.,A;B¢~o~_O~airwell Change approved program (::~:~efa~ shutdown__ Re-enter suspended well Plugging~ Time extension Stimulate Pull tubing ~ Variance ~ Perforate ~ 2_ Name of Operator Shell Western E&P Inc. 3. Address (I(.~2~K -5"7-7~~3 P.O. BOX 576, Houston, TX 77001-0576 5. Type of Well: Development Exploratory 4. LooMion of we~l at surface PLATF A, LEG 2, COND 12, 1677' FSL & 367' FEL 511, T8N, R13W, S.M. At top of productive interval e 8500' MD, 4820' FSL & 368' FEL Sll, T8N, R13W, S.H. At effective depth At total depth ~ 12,170' MD, 2174' FSL & 4907' FEL 51, T8N, R13W, S.M. 6. Datum elevation (DF ~ KB) 116' KB 7. Unit o~ Property name MIDDLE GROUND SHOAL 8. Well number 9. Permit number 86-25 10. APl number ~o- 733-20179-02 11. Field/Poc~ Total depth: measured .~. 7765 feey Plugs (~l~easured) truevert~_~ 7760.1 f~ / Effective depth: measured 7560 feet '""~nlt~(measured ) iPi~u°t~' (.~/' 7"////'~'~ 824 /~ L~ 7765'_ 7151' foot True vertical depth 2-3/8', 4.7#° N-80 EUE e 6051'; 2-3/8" 4.7#, N-80 EUE e 6526' P~Y~,ers ~ SSSV (type m~d measured depth) OTIS RDH PKR Ia 6033'; BAKER "DB" PKR [a 6436' 13. Attm~ments Description summary of proposal X Detailed operations p~ogram 14. Estimated date for commencing operation 8/8/95 16. ff p~oposal was verbally approved Name of approver Date spp~oved 15. Status of we~l classif~ation as: Oil Gas serv~e X Suspended 17. I hereby certify that the foregoing is true and correct to the b~st of my knowledge. ,0. G.S. - ASSET Signed //~ ' FOR COMMISSION USE ONLY Date 7/31/95 Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE /ELL PERMIT CHECKLIST MINISTRATION 1- 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Y Lease number appropriate ................ Unique well name and number ............... Y Well located in a defined pool ............. Well located proper distance from drlg unit boundary.. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval.. Can permit be approved before 15-day wait ....... Y .Y .Y Y .Y Y N N N N N N N N N N N N N NGINEERING WELL NAME GEOL AREA 15. Surface casing protects all known USDWs ......... 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ............... ~ ..... psig.~ 26. BOPE press rating adequate; test to 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ PROGRAM: exp [] dev [] redrll~ serv [] GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones. .... Y 32. Seismic analysis 9f shallow gas zones... , ...... ~/ N 33. Seabed condition survey (if off-shore) ....... ./~Y N -- 34. Contact name/phone for weekly progress reports . . J.. Y N [exploratory only] GEOLOGY: Comments/Instructions: CD