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100-266
THE STATE Of , 11_21/J���� GovERNOR SEAN PARNEI.1. Mr. Stan Golis Operations Manager — Cl Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No -Flow Verification Granite Point State 31-14RD2 PTD 1002660 Dear Mr. Golis: September 16, 2014 N'.k. 0 iil' 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 On July 9, 2014 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Granite Point State 31-14RD2 located on the Granite Point Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). A subsurface safety valve is not required to be installed in this well based on the no -flow test result. A fail- safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up to Granite Point State 31-14RD2. The no - flow test consisted of a series of flow and shut in periods. During the flow monitoring periods, no liquid production was observed and measured gas flow rates decreased from a high rate of 800 scf/hour to less than 200 scf/hour in 15 minutes. Pressures during the test remained less than 1 psi. The test results meet AOGCC acceptance criteria for a passing no flow test. The subsurface safety valve must be returned to service if Granite Point State 31-14RD2 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Granite Point Platform. Sincerely, aure�� % s B. Regg T Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, August 27, 2014 3:19 PM To: 'Daniel Taylor' Subject: RE: GPS 31-14RD2 (PTD 100-266) Dan, Thanks for the letter... we found the report from Lou and indeed the well passed a no flow test. None the less, a sundry should have been submitted to install the velocity string as it still defeated the ScSSV without prior written consent from the AOGCC. You also pulled two tubing patches and did not replace them. When I discussed not needing sundries for pulling patches the intent was that they would be replaced after wellwork was completed and tubing integrity was restored . In this case they were pulled and not replaced in order to run the CT string. In the future when you are preparing wellwork procedures make sure you consider whether or not a sundry is needed. If in doubt always give me a call. Guy Schwartz Senior 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: Daniel Taylor [mailto:dtaylor@hilcorp.com) Sent: Monday, August 25, 2014 5:16 PM To: Schwartz, Guy L (DOA) Subject: RE: GPS 31-14RD2 (PTD 100-266) Guy, Please see the attached correspondence from Mr. Marty Askin on the Granite Point Platform. Mr. Grimaldi informed Marty that Hilcorp will get a letter of approval after it makes it through the proper chain. Regards, Dan Taylor Operations Engineer Hilcorp Alaska, LLC. O: 907-777-8319 C: 907-947-8051 SCpjM OCT 022014, From: Schwartz, Guy L (DOA)[ma ilto: guy. schwa rtz@alaska.gov] Sent: Monday, August 25, 2014 1:13 PM To: Daniel Taylor Subject: RE: GPS 31-14RD2 (PTD 100-266) Dan, This well needs to have a witnessed no flow test to continue production as it is set up now. We don't have any record of a "verbal No Flow " waiver given. Guy Schwartz Senior 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 (Guv.schwartz@alaska.aov). From: Daniel Taylor [mailto:dtaylor@hilcorp.com] Sent: Monday, August 25, 2014 1:07 PM To: Schwartz, Guy L (DOA) Subject: RE: GPS 31-14RD2 (PTD 100-266) With the well making upwards of 215bpd with 98% water we are still not at the bottom valve. Without the mandrels we would not have had the available GL pressure to get out the end of the CT string. Regards, Dan Taylor Operations Engineer Hilcorp Alaska, LLC. O: 907-777-8319 C: 907-947-8051 From: Schwartz, Guy L (DOA) [mailto:guy.schwariz@alaska.govl Sent: Monday, August 25, 2014 11:35 AM To: Daniel Taylor Subject: RE: GPS 31-14RD2 (PTD 100-266) OK... that helps. But why run GLMs in the CT tubing string if you don't have a functioning packer? Guy Schwartz Senior 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: Daniel Taylor fmailto:dtaylor@hilcorp.com] Sent: Monday, August 25, 2014 10:35 AM To: Schwartz, Guy L (DOA) Subject: RE: GPS 31-14RD2 (PTD 100-266) Guy, We perforated this well last month and received a verbal no -flow from Mr. Regg on 7-9-14. This was a preliminary measure to ensure that the SCSSSV could be safely locked out. There are no patches in the tubing at present and there is no packer at the bottom of the CT string. There was a BOP test prior to getting in the well (see attached). I spoke with Mr. Lou Grimaldi the day before (while he was on the Anna Platform) concerning BOP tests for coil tubing. He informed me that we could proceed as long as the request was submitted. The installation procedure consisted of the coil tubing connectors and the coil tubing hanger. Please see the makeup procedure for these two activities. Thank you sir. Regards, Dan Taylor Operations Engineer Hilcorp Alaska, LLC. O: 907-777-8319 C. 907-947-8051 From: Schwartz, Guy L (DOA) [ nailto;guy.schwa rtz-@alaska.gov] Sent: Monday, August 25, 2014 9:59 AM To: Daniel Taylor Subject: GPS 31-14RD2 (PTD 100-266) Dan, I just got a 10-404 for this well for running a CT velocity string. We should have gotten a 10-403 for this work before you did the wellwork. Three reasons ... 1. The ScSSV is now locked out due to the installation which we want to know beforehand. 2. For notification that CT work was ongoing for possible BOP test witness 3. Also this is not a typical velocity string for a gas well. Looks more like a new tubing string.... can't tell if you landed CT seals in the Q nipple for a new packer or not. Was new IA tested for integrity since the tubing patches are now gone. Nothing in the 10-404. Please send me your actual wellwork procedure that was sent to the field. Guy Schwartz Senior 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). If 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.Qovov). 4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other [D Install Velocity String Performed: Alter Casing ❑ Pull Tubing[] Stimulate - Frac ❑ Waiver ❑ Time Extension El Change Approved Program ❑ Operat. Shutdown[] Stimulate - Other ❑ Re-enter Suspended Well 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 2 Stratigraphic❑ Exploratory ❑ Service ❑ 100-266 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, Alaska 99504 50-733-10061-02 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018761 Granite Pt St 31-14RD2 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Granite Point Field / Middle Kenai Oil 11. Present Well Condition Summary: EC E I V E Total Depth measured 10,191 feet Plugs measured 10,178 feJR true vertical 9,700 feet Junk measured 10,019 (fill) feet AUG 2 2 2014 Effective Depth measured 10,090 feet Packer measured 9,057 feet true vertical 9,604 feet true vertical 8,594 feet ASG^C Casing Length Size MD TVD Burst Collapse Structural Conductor 618' 20" 618' 618' Surface 2,328' 13-3/8" 2,328' 2,221' 3,090 psi 1,540 psi Intermediate 4,783' 9-5/8" 4,783' 4,459' 5,750 psi 3,090 psi Production 10,191' 7" 10,191' 9,702' 6,340 psi 3,830 psi Liner Perforation depth Measured depth (See Attached Schematic) OCT o2 2a14 True Vertical depth (See Attached Schematic) Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / L-80 9,716' MD 9,238' TVD Otis RH 9,057' MD Otis 320' MD Packers and SSSV (type, measured and true vertical depth) Retrievable Packer 8,594' TVD Ball Valve 320' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 87 87 Subsequent to operation: 5 26 192 1120 115 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ DevelopmentQ Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas ❑ WDSPL❑ IGSTOR ❑ 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: N/A Contact Dan Taylor Email dtaylor(Whilcorp.com Printed Name Dan Taylor Title Operations Engineer Signature Phone 907-777-8319 Date 8/22/2014 Form 10-404 Revised 10/2012 FISEMS 1: Submit Original Only 9-5/8'Q 3 TOC @ 8,200' (temp log) i'. RTV PKR MD.9,057ft 3 T V D: 8,594ft INC: 12° Orifice to C-2 C-6 Top - 178ft T V D i C-3 ECT MD: 9,716ft TVD: 9,238ft 4 C-5 INC: 14' R C-6 PBTD = 10,178' TD = 10,191' MAX HOLE ANGLE = 27° @ 4,300' SCHEMATIC CASING DETAIL Granite Point Field Well #: GP 31-14RD2 Completed: 9/67 Size RKBtoMWL=105.9' Grade Conn 1 20" Btm 20" Top(TVD) Prior Ptch: 1 320' 14 7 ft to 618' 13-3/8" 223ft MD K-55 13-3/8" 12.515 1 V -String 9-5/8" 40 OD Max of LTC G Manel Assem 4,783' 2.992 2.125" rlor Ptch: STC 6.366 618ft to 3,693' C-6 644ft M D P-110 LTC 6.276 ' S 4,693' 'r or Ptch. 23 N-80 8 68f to 6.366 4,693' 8 94f MD 2 23 N-80 M 9-5/8'Q 3 TOC @ 8,200' (temp log) i'. RTV PKR MD.9,057ft 3 T V D: 8,594ft INC: 12° Orifice to C-2 C-6 Top - 178ft T V D i C-3 ECT MD: 9,716ft TVD: 9,238ft 4 C-5 INC: 14' R C-6 PBTD = 10,178' TD = 10,191' MAX HOLE ANGLE = 27° @ 4,300' SCHEMATIC CASING DETAIL Granite Point Field Well #: GP 31-14RD2 Completed: 9/67 Size WT Grade Conn ID Top Btm 20" Top(TVD) Tubing hanger. 1 320' Surf 618' 13-3/8" 61 K-55 STC 12.515 Surf 2,328' 9-5/8" 40 N-80 LTC 8.835 Surf 4,783' 2.992 23 N-80 STC 6.366 Surf 3,693' C-6 26 P-110 LTC 6.276 3,693' 4,693' 5,280' 23 N-80 Seal Lock 6.366 4,693' 6,317' 7" 23 N-80 LTC 6.366 6,317' 8,733' 6,921' 29 N-80 LTC 6.184 8,733' 9,108' 9,664' 29 P-110 X -line 6.184 9108' 10,191' TUBING DETAIL 3-1/2" 1 9.2 1 L-80 BTC 1 2.992 1 38' 9,716' JEWELRY DETAIL No MD TVD ID Item Zone Top(MD) Btm(MD) Top(TVD) Tubing hanger. 1 320' 320' 2.75 Otis Ball Valve, w/ 1.5" ID thru ball. 8,695' 2,251' 2,151' 2.992 3-1/2" Camco KBM 8,699' 2,468 2,350 C-3 IM GL Mandrel 9,600' 3,760' 3,537' 2.992 3-1/2" Camco KBM 9,680' 4,495 4,200 9,247' IM GL Mandrel C-6 4,775' 4,452' 2.992 3-1/2" Camco KBM 20 5,672' 5,280' 2.992 3-1/2" Camco KBM 9,356' 6,111 5,700 9,880' IM GL Mandrel 2 6,360' 5,940' 2.992 3-1/2" Camco KBM 9,974' 6,921' 6,495' 2.992 3-1/2" Camco KBM 9,980' 7,330 6,900 9,664' IM GL Mandrel C 7 7,578' 7,146' 2.992 3-1/2" Camco KBM 10 8,083' 7,642' 2.992 3-1/2" Camco KBM 8,296 7,850 IM GL Mandrel 8,584' 8,132' 2.992 3-1/2" Camco KBM 9,012 8,550 IM GL Mandrel 3 9,057' 8,594' 2.78 Otis Model "RH" Retrievable Pkr. 2 9,575 9,100 Orifice 4 9,681' 9,204' 2.635 Otis "Q" No -Go Profile Nipple, 2.75 5 9716' 9238' CT Bull Plug 6 9,716' 9,238' 2.992 Ball Catcher Sub \A/IRFI IMF DRr1Rl FRAC Worked 2.25" GR through GLM 10/8/96 Perforations 3780' WLM 2.25" IB impression of a damaged latch or RS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount C-2 9,140' 9,160' 8,675' 8,695' 20 9,165' 9,185' 8,699' 8,719' 20 C-3 9,445' 9,600' 8,974' 9,125' 155 C-5 9,680' 9,725' 9,203' 9,247' 45 C-6 9,757' 9,777' 9,278' 9,298' 20 9,807' 9,837' 9,327' 9,356' 30 C-6 9,880' 9,910' 9,398' 9,427' 30 9,940' 9,974' 9,457' 9,490' 34 9,980' 10,152' 9,496' 9,664' 172 C 7 10,180' 10,190' 9,692' 9,701' 10 \A/IRFI IMF DRr1Rl FRAC Worked 2.25" GR through GLM 10/8/96 @ 3780' WLM 2.25" IB impression of a damaged latch or RS 10/8/96 @ 4779' WLM 2.3" Tapered Swedge, knocked GLV back into pocket 10/25/96 @ 4779' WLM Fill Tagged w/ 2.30" Tapered Swedge 10/25/96 @ 10,090' WLM Revised By JILL 08/22/14 Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GRANITE PT ST 431-14RD2 50-733-10061-02 100-266 1 7/27/14 7/28/14 Daily Operations: 07/23/14 - Wednesday 07/24/14 - Thursday 07/25/14 - Friday 07/26/14 -Saturday 07/27/14 - Sunday CTU crew fly from OSK to Granite Point. Orientation and pre -job safety meeting. Begin CTU rig up. Rig up complete. Pressure test surface equipment, Low 250 psi, High 3500 psi. PT good. Bleed down and unstab for tools. Make up CT connector to mandrel #1. Make up bull plug to bottom of mandrel. RIH with mandrel #1557'. Close in BOP rams. Bleed off lubricator. Unstab lubricator. Cut pipe. Make up CT connectors to mandrel #2. Stab back onto lubricator. Pressure up lubricator. Pull test. Open BOP rams. RIH with mandrel #2 710'. Close in BOP rams. Bleed off lubricator. Unstab lubricator. Cut pipe. Make up CT connectors to mandrel #3. Stab back onto lubricator. Pressure up lubricator. Pull test. Open BOP rams. RIH with mandrel #3 960'. Close in BOP rams. Bleed off lubricator. Unstab lubricator. Cut pipe. Make up CT connectors to mandrel #4. Stab back onto lubricator. Pressure up lubricator. Pull test. Open BOP rams. RIH with mandrel #4 1,213'. Close in BOP rams. Bleed off lubricator. Unstab lubricator. Cut pipe. Make up CT connectors to mandrel #5. Stab back onto lubricator. Pressure up lubricator. Pull test. Open BOP rams. RIH with mandrel #5 1,610'. Close in BOP rams. Bleed off lubricator. Unstab lubricator. Cut pipe. Make up CT connectors to mandrel #6. Stab back onto lubricator. Pressure up lubricator. Pull test. Open BOP rams. RIH with mandrel #6 2,021'. Close in BOP rams. Bleed off lubricator. Unstab lubricator. Cut pipe. Make up CT connectors to mandrel #7. Stab back onto lubricator. Pressure up lubricator. Pull test. Open BOP rams., RIH with Mandrel #7 2,457'. Close in BOP rams. Shutdown for the night. Turn well over to production. 07/28/14 - Monday Morning tool box meeting. Fire up CTU equipment and prepare to land velocity string. Coil is in the hole @ 2,457'. Pull test station #7 mandrel against closed rams. Pull test good. Cut coil and make up CT connector and Landing sub. Make up GS spear. Stab lubricator back on well and pressure up lubricator. Open rams and land velocity string in tubing hanger. Run screws down on hanger and pressure test hanger to 5000 psi. Pressure test good. Shear off of v -string with GS. Turn well over to production. Begin rig down of CTU. Rig down complete. Depart Granite point and fly to OSk. 07/29/14 -Tuesday V/ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑� Other R] Remove Patches Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re-enter Suspended Well[] 2. Operator Name: Hilcorp Alaska, LLC 4. Well Class Before Work: Development R] Stratigraphic❑ Exploratory ❑ Service ❑ 5. Permit to Drill Number: 100-266 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, Alaska 99504 50-733-10061-02 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018761 Granite Pt St 31-14RD2 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Granite Point Field / Middle Kenai Oil 11. Present Well Condition Summary: Total Depth measured 10,191 feet Plugs measured 10,178 fee E C I Y.r true vertical 9,700 feet Junk measured 10,019 (fill) feet JUL 3 0 2014 Effective Depth measured 10,090 feet Packer measured 9,057 feet true vertical 9,604 feet true vertical 8,594 feet ����� Casing Length Size MD TVD Burst Collapse Structural Conductor 618' 20" 618' 618' Surface 2,328' 13-3/8" 2,328' 2,221' 3,090 psi 1,540 psi Intermediate 4,783' 9-5/8" 4,783' 4,459' 5,750 psi 3,090 psi Production 10,191' 7" 10,191' 9,702' 6,340 psi 3,830 psi Liner Perforation depth Measured depth (See Attached Schematic) True Vertical depth (See Attached Schematic) Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / L-80 9,716' MD 9,238' TVD Otis RH 9,057' MD Otis 320' MD Packers and SSSV (type, measured and true vertical depth) Retrievable Packer 8,594' TVD Ball Valve 320' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 85 85 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Developments Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 0 Gas ❑ WDSPL❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ 3USP❑ 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: 1314-369 Contact Dan Taylor Email dtaylor(Whilcorp.com Printed Name Dan Tay �Z' Title Operations Engineer Signature Phone 907-777-8319 Date 7/30/2014 Form 10-404 Revised 10/2012 01 ',/%�/ S` t nIIUL 3 120 "e Vel SCHEMATIC Granite Point Field Well #: GP 31-14RD2 Ilileinp :1I..ku. LLf. Completed: 9/67 CASING DETAIL 20" EOl RKB to MWL = 105.9' PBTD = 10,178' TD = 10,191' MAX HOLE ANGLE = 27° @ 4,300' Size WT Grade Conn ID Top Btm 20" 1 320' 2.75 Otis Ball Valve, w/ 1.5" ID thru ball. Surf 618' 13-3/8" 61 K-55 STC 12.515 Surf 2,328' 9-5/8" 40 N-80 LTC 8.835 Surf 4,783' 2 23 N-80 STC 6.366 Surf 3,693' 3-1/2" Camco KBM , Side Pocket Mandrels 26 P-110 LTC 6.276 3,693' 4,693' C-5 23 N-80 Seal Lock 6.366 4,693' 6,317' 7" 23 N-80 LTC 6.366 6,317' 8,733' 5 29 N-80 LTC 6.184 8,733' 9,108' 29 P-110 X -line 6.184 9108' 10,191' TUBING DETAIL 3-1/2" 9.2 1 L-80 I BTC 1 2.992 1 38' 9,716' JEWELRY DETAIL No Depth ID Item Btm(TVD) Amount Condition Tubing hanger. 1 320' 2.75 Otis Ball Valve, w/ 1.5" ID thru ball. 1 2,251' 3-1/2" Camco KBM , Side Pocket Mandrels 9,110' 3,760' 8,646' 3-1/2" Camco KBM , Side Pocket Mandrels Cmt Sqzd 4,775' 9,140' j 3-1/2" Camco KBM , Side Pocket Mandrels 8,675' 5,672' 20 3-1/2" Camco KBM , Side Pocket Mandrels 2 6,360' 9,185' 3-1/2" Camco KBM , Side Pocket Mandrels 8,719' 6,921' Open f/ Prod. 3-1/2" Camco KBM , Side Pocket Mandrels 9,445' 7,578' 8,974' 3-1/2" Camco KBM , Side Pocket Mandrels 155 8,083' C-5 3-1/2" Camco KBM , Side Pocket Mandrels 9,725' 8,584' 9,247' 3-1/2" Camco KBM , Side Pocket Mandrels 3 9,057' 2.78 Otis Model "RH" Retrievable Pkr. 4 9,681' 2.635 Otis "C!" No -Go Profile Nipple, 2.75 5 9,716' 2.992 Ball Catcher Sub PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount Condition @ 9,084' 9,085' 8,620' 8,621' 1 Cmt Sqzd 9,109' 9,110' 8,645' 8,646' 1 Cmt Sqzd 9,140' 9,160' 8,675' 8,695' 20 Open f/ Prod. C-2 9,165' 9,185' 8,699' 8,719' 20 Open f/ Prod. C-3 9,445' 9,600' 8,974' 9,125' 155 Open f/ Prod. C-5 9,680' 9,725' 9,203' 9,247' 45 Open f/ Prod. C-6 9,757' 9,777' 9,278' 9,298' ±20' Open f/ Prod. 9,781' 9,782' 9,302' 9,302' 1 Cmt Sqzd 9,807' 9,837' 9,327' 9,356' 30 Open f/ Prod. C-6 9,880' 9,910' 9,398' 9,427' 30 Open f/ Prod. 9,940' 9,974' 9,457' 9,490' 34 Open f/ Prod. 9,980' 10,152' 9,496' 9,664' 172 Open f/ Prod. C 7 10,180' 10,190' 9,692' 9,701' 10 Covered w/ Fill WIRELINE PROBLEMS Worked 2.25" GR through GLM 10/8/96 @ 3780' WLM 2.25" IB impression of a damaged latch or RS 10/8/96 @ 4779' WLM 2.3" Tapered Swedge, knocked GLV back into pocketl0/25/96 @ 4779' WLM Fill Tagged w/ 2.25 pump bailer 06/29/14 @ 10,090' WLM Revised By 1LL 07/30/14 Hilcorp Alaska LLC ' Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 31-14RD2 50-733-10061-02 100-266 6/28/2014 6/29/14 Daily Operations: 06/28/14-Saturday Rig up slickline. Pressure test surface equipment to 2000 psi. RIH with 2.75" gauge ring. Tag top of pack off assembly @ 1,146' WLM. POOH. RIH with 3" GS pulling tool. Latched and pulled top AA stop @ 1,146' WLM. POOH. Recovered stop. RIH with 3" GS pulling tool. Latched and pulled top P/0 with 35' spacer @ 1,147' WLM. POOH. Recovered assembly. RIH with 3" GS pulling tool. Latched 35' spacer assembly @ 1,184' WLM. Jar up repeatedly. POOH. Brass pin sheared on GS. Repinned GS with steel. RIH with 3" GS pulling tool. Latched and pulled 35' spacer assembly @ 1,184' WLM. Jar up repeatedly. POOH. Recovered assembly. RIH with 3" GS pulling tool. Latched and pulled bottom P/0 @ 1,221' WLM. POOH. Recovered bottom P/0 assembly. RIH with 3" GS pulling tool. Latched and pulled bottom AD-2 tubing stop @ 1,222' WLM. POOH. Recovered AD-2 stop. Lay down slickline for the night. Turn well over to production. 06/29/14 - Sunday Rig up slickline. Pressure test surface equipment to 2000 psi. RIH with 2.75" gauge ring. Clean run to top of pack off assembly @ 5,619' WLM. POOH. RIH with 3" GS pulling tool. Latched and pulled AA stop @ 5,619' WLM POOH. Recovered AA stop. RIH with 3" GS pulling tool. Latched and pulled top pack off assembly @ 5,620' WLM. POOH. Recovered top pack off, 10' spacer pipe. RIH with 3" GS pulling tool. Latched and pulled bottom pack off assembly @ 5,634' WLM. POOH. Recovered pack off, 10' spacer. RIH with 3" GS pulling tool. Latched and pulled bottom AD-2 tubing stop @ 5,645' WLM. POOH. Recovered AD-2 tubing stop. RIH with 2.75" gauge ring. Clean run to top of pack off assembly @ 6,864' WLM. POOH. RIH with 3" GS pulling tool. Latched and pulled AA stop @ 6,864' WLM POOH. Recovered AA stop. RIH with 3" GS pulling tool. Latched and pulled top pack off assembly @ 6,865' WLM. POOH. Recovered top pack off, 10' spacer pipe. RIH with 3" GS pulling tool. Latched and pulled bottom pack off assembly @ 6,876' WLM. POOH. Recovered bottom pack off, 10' spacer pipe. Jun 29 2014 ENGINEER: FIELD SUPERVISOR: Chris Boren PRESENT OPERATIONS: Pull Patches for perforation work. Slick line crew departs from OSK headed to Granite Point.; Orientation for crew and pre -job safety meeting. Fill out permit to work and JSA.;Move slickline unit into place and shuffle equipment for space around weli.;Rig up Slickline. Pressure test surface equipment to 2000 psi.;RIH with 2.75" gauge ring. Tag top of pack off assembly @ 1146' WLM. POOH.;RIH with 3" GS pulling tool. Latched and pulled top AA stop @ 1146' WLM. POOH. Recovered stop.;RIH with 3 GS pulling tool. Latched and pulled top P/O with 35' spacer @ 1147' WLM. POOH. Recovered assembly.;RIH with 3" GS pulling tool. Latched 35' spacer assembly @ 1184' WLM. Jar up repeatedly. POOH. Once on surface we found that the brass pin had sheared on GS. Repinned GS with steei.;RIH with 3" GS pulling tool. Latched and pulled 35' spacer assembly @ 1184' WLM. Jar up repeatedly. POOH. Recovered assembly.;RIH with 3" GS pulling tool. Latched and pulled bottom P/0 @ 1221' WLM. POOH. Recovered bottom P/O assembiy.;RIH with 3" GS pulling tool. Latched and pulled bottom AD -2 tubing stop @ 1222' WLM. POOH. Recovered AD -2 stop.;Lay down slickline for the night.;Turn well over to Droduction. Jun 30 2014 ENGINEER: FIELD SUPERVISOR: Chris Boren PRESENT OPERATIONS: Pull Patches for perforating. Fill out permit to work and ISA. Rig up slickline. Pressure test surface equipment to 2000 psi.;RIH with 2.75" gauge ring. Clean run to top of pack off assembly @ 5619' WLM. POOH.;RIH with 3" GS pulling tool. Latched and pulled AA stop @ 5619' WLM POOH. Recovered AA stop.;RIH with 3" GS pulling tool. Latched and pulled top pack off assembly @ 5620' WLM. POOH. Recovered top pack off, 10' spacer pipe.;RIH with 3" GS pulling tool. Latched and pulled bottom pack off assembly @ 5634' WLM. POOH. Recovered pack off, 10' spacer.;RIH with 3" GS pulling tool. Latched and pulled bottom AD -2 tubing stop @ 5645' WLM. POOH. Recovered AD -2 tubing stop.;RIH with 2.75" gauge ring. Clean run to top of pack off assembly @ 6864' WLM. POOH.;RIH with 3" GS pulling tool. Latched and pulled AA stop @ 6864' WLM POOH. Recovered AA stop.;RIH with 3" GS pulling tool. Latched and pulled top pack off assembly @ 6865' WLM. POOH. Recovered top pack off, 10' spacer pipe.;RIH with 3" GS pulling tool. Latched and pulled bottom pack off assembly @ 6876' WLM. POOH. Recovered bottom pack off, 10' spacer pipe.;RIH with 3" GS pulling tool. Latched and pulled bottom AD -2 tubing stop @ 6891' WLM. POOH. Recovored AD -2 stop.;RIH with 2.50" gauge ring. Unable to work past 9616 WLM. POOH.;RIH with 2.25 pump bailer. Worked bailer 9616' WLM. Fell down hole and continued working bailer until debris fell past EOT. Ran to top of fill @ 10019' WLM. POOH.;RIH with 2 1/8" x 25' aluminum dummy gun. Clear run to 9780' WLM. POOH.;Rig down slickline. Rig up a -line. Set up and arm 20' Perf gun.;Pressure test a -line surface equipment to 1500 psi.;RIH with 2" x 21' gun with gamma ray / CCL.;Log correlation pass from 9900' WLM to 9600' WLM. Shoot interval 9757' WLM to 9777' WLM. POOH. Shot was successful.;Rig down e-Iine;Turn well back over to production. MEMORANDUM TO: Jim Regg 7��"(� P. I. Supervisor FROM: Lou Grimaldi Petroleum Inspector SCANNED NOV 20 2014 State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 11, 2014 SUBJECT: No Flow Verification Granite Point Platform Granite Pt St 31-14 RD2 PTD 1002660 Hilcorp Alaska LLC Granite Point Field Wednesday, July 09, 2014; 1 witnessed the No -Flow test on Hilcorp's Granite Point Platform, Well # 31-14RD2 in the Granite Point Field. Marty Askins, lead production operator, assisted me during my test today. The pressure was read on a recently calibrated Erdco, Armor -Flo resistance style gas flow meter (SN #062532) capable of measuring 200 to 2000 scf/hr and a recently calibrated 30 psi 5" test gage w/0.2 psi increments. I supplemented the pressure readings by submerging the bleed hose in a 5 gallon bucket filled with water and measuring where the hydrostatic pressure would stop the gas bleeding. The well was static when I arrived with 0 psi on the tubing/annulus. The annulus was open to the tubing. I observed the well for approximately 4 hours with little or no discernible flow after short "Blow Down" periods. The well exhibited proper parameters for a no -flow status. The following table contains the steps, pressures and flow rates observed. (',PF l;ranite Point Platform 31-14RD2 No Flow Test 07/09/14 (Lou Grimaldi) Chrono 10:26(psi) Operation Pressure Flow sc 00:00 Bare whisper from hose, line up to 2" of water. 0 >0 00:15 Well flowing to bucket, barely bubbling 0.1 >0 00:30 Shut-in well. 0.1 ------- 00:35 Well Shut-in. 0.3 ------- 00:45 Well Shut-in. 0.4 ------- 00:60 Well Shut-in. 0.4 ------- 01:30 Well Shut-in. Open to Flow 0.5 800 - 01:35 Bleeding through Flow Meter. 0.3 600 01:40 Bleeding through Flow Meter. 0.1 400 2014-0709_No-Flow_GranitePt_State_31-14RD2_1g.docx 1 of 2 01:45 Bleeding through Flow Meter. >0 <200 02:00 Bleeding through Flow Meter. Shut-in >0 <200 02:05 Well Shut-in. 0.2 ------- 02:15 Well Shut-in. 0.4 ------- 02:30 Well Shut-in. Open to Flow 0.4 <700 02:35 Bleeding through Flow Meter. 0.1 250 02:40 Bleeding through Flow Meter. 0.1 200 02:45 Bleeding through Flow Meter. 0 200 03:00 Bleeding through Flow Meter. Shut-in 0 <200 I concluded the test at this point. The hose end was barely bubbling at 1 inch of water (<0.4 psi). Attachments: Test equipment calibration certificates (2) v Non -Confidential 2014-0709_No-Flow_GranitePt_State_31-14RD2_lg.docx 2 of 2 NoRc,) T'e-s 4— -- Crmtyte P� 5�,� 31-4A)L -1i`t�14 CGrtL�Cate LkO cp 4 124 This is to certify that this instrument has been calibrated for the fluid conditions specified on the purchase order and embossed on the nameplate. Measuring devices that are traceable to the United States National Institute for Standards and Technology (NIST - formerly National Bureau of Standards) were used for this calibration. Achian Date Q�o2532 Instrument Serlal Number ERDCO Engineering Corporation 721 Custer Av ♦ post Office Box 6318 Evanston, IL 60204-6318 USA MMI Presswv' Cott ko HILCORP rk-""OALIBRATION CERTIFICATE Pressm-c Standards Rderenced to Nls,r VIICM822-256610-96., TN838-256609-96, 11-8523 Gauge type: r (V" col.` Pressure range: I.D. Mlrnber: Date: TEST PRESSURE INDICATION 0 -.- 5D Calibrated by: A\.V\M Test equipment S/N: , .. - ------------ This certificate expires in 90 days on For recertification, contact Gina Bogart 776-6825, THE STATE �. 17-14 7- �,. GOVERNOR SEAN PARNE A - Dan Taylor Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Pool, Granite Pt St 31-14RD2 Sundry Number: 314-369 Dear Mr. Taylor: 333 West Sevenlh Avenue Anchorage, Alaska 99501-3572 Nc;;": X07.279.1433 ox: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED this L9" day of June, 2014. Encl. Sincerely, U �Q Cathy P Foerster Chair SCANNED OCT 0 2 2014 RECEIVED STATE OF ALASKA JUN 16 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION IO 61 1 ci r / 4- APPLICATION FOR SUNDRY APPROVALS � RGCC ,)n nnrr, )�n 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate [ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Remove / Reinstall Patch(s) D 2. Operator Name: 4. Current Well Gass: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Stratigraphic ❑ Service ❑ 100-266 - 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-10061-02 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 Will planned perforations require a spacing exception? Yes I—]No 121 Granite Pt St 31-14RD2 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018761 I Granite Pt Field / Middle Kenai Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,191 9,700 10,090 9,604 10178 10,090 (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 618' 20" 618' 618' Surface 2,328' 13-3/8" 2,328' 2,221' 3,090 psi 1,540 psi Intermediate 4,783' 9-5/8" 4,783' 4,459' 5,750 psi 3,090 psi Production 10,191' 7" 10,191' 9,702' 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2# L-80 9,716' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Otis RH Ret. Pkr / Otis Ball Valce 9,057' (MD) 8,594' (TVD) /320' (MD) 320' (T` 12. Attachments: Description Summary of Proposal 171 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development El Service ❑ 14. Estimated Date for 6/26/2014 15. Well S atu after proposed work: Commencing Operations: Oil ( Gas ❑ WINJ ❑ GINJ ❑ WDSPL ❑ Suspended ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dtaylor hilcorg.com Printed Name Dan Ta a Title Operations Engineer Signature Phone (907) 777-8319 Date 6/16/2014 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: Spacing Exception Required? Yes ❑ No ( Subsequent Form Required: APPROVED BY Approved by: V L�.` COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-403 (Revised 10/2012) Approv QRIIGs[ t nths from the date of approval. Attachments it or lNS J� REC19181 I ilcorp Alaska, LU Well Prognosis Well: GP 31-14RD2 Date: 6/16/2014 Well Name: GP 31-14RD2 API Number: 50-733-10061-02 Current Status: Producer Leg: 1 Estimated Start Date: June 26, 2014 Rig: N/A Reg. Approval Reqftd? 10-403 Date Reg. Approval Recftvd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 100-266 First Call Engineer: Dan Taylor 907 777-8319 O 907 947-8051 M Second Call Engineer: I Reid Edwards 907 777-8421 O AFE Number: Current Bottom Hole Pressure Maximum Expected BHP Max. Potential Surface Pressure: Brief Well Summary 2,779 psi at 9,515ft TVD / 10,000ft MD 2,779 psi at 9,515ft TVD / 10,000ft MD 764 psi From SBHP Survey 20013 From SBHP Survey 20013 2,779psi — (0.1 psi/ft * 2/3 * TVD + 0.435psi/ft * 1/3 * TVD) GP 31-14RD2 was completed in 1967 as a gas lifted producer. It was taken offline as it produced large amounts of water with minimal oil. Patches were re -installed in September of 2012 and the well was brought back on line with no change in performance. This application for Sundry approval outlines the procedure for removing the patches, perforating the C-6 sands (+/-9,757ft to +/-9,777ft MD), and re -installing the patches. Procedure 1. Identify and record fluid level. 2. Hold pre -job safety meeting. 3. Prepare well for a -line perforating. a. Check well head pressure. b. Ensure crown and wing valves are closed. c. Bleed pressure from well head. d. Ensure there is no trapped pressure. e. Ensure there is proper lighting for operations. f. Keep excess personnel away from operations. g. Ensure perforating unit is grounded. 4. Rig up wireline valves, lubricator, head catcher, grease injection head, pack -off, line wiper and wire line. a. Test lubricator to 1.00O12si. b. Max potential surface pressure—764psi. 5. Run in hole with 2.75in gauge ring to top of pack -off assembly at 1,147ft to ensure there are no obstructions. 6. Run in hole with GS pulling tool. a. Pull pack -off assembly at 1,147ftto 1,223ft. 7. Run in hole with 2.75in gauge ring to top of pack -off assembly at 5,618ft to ensure there are no obstructions. 8. Run in hole with GS pulling tool. a. Pull pack -off assembly at 5,618ft to 5,644ft. 9. Run in hole with 2.75in gauge ring to top of pack -off assembly at 6,868ft to ensure there are no obstructions. 10. Run in hole with GS pulling tool. a. Pull pack -off assembly at 6,868ft to 6,894ft. 11. Run in hole with 2.50in gauge ring to estimated top of fill at 10,090ft. 12. Run in hole with 2.125in x 25ft dummy gun to below EOT at +/-9,716ft. 13. Rig Down slick line. 14. Rig up E -Line and pressure control equipment. 15. Run in hole with 2in x +/-21ft perforating gun to +/-9,757ft. Log correlation pass verifying depth. V,, 16. Pull gun into position to shoot interval from +/-9,757ft to +/-9,777ft. 17. Pull out of hole. Rig down E -Line. 18. Rig up slick ine. 19. Rig up wireline valves, lubricator, pack -off, and line wiper. 20. Run in hole with pack -off assembly. V a. Set at +/-6,894ft to +/-6,868ft. 21. Run in hole with pack -off assembly. a. Set at +/-5,644ft to +/-5,618ft. Hilcorp Alaska, LLi 22. Run in hole with pack -off assembly. a. Set at +/-1,223ft to +/-1,147ft. 23. Rig down slick line. 24. Turn well over to production. _ a. 1224 r Ao to Attachments: 1. As -built Well Schematic. 2. Proposed Well Schematic. 3. Wire Line Surface Equipment Diagram. Well Prognosis Well: GP 31-14RD2 Date: 6/16/2014 SCHEMATIC Granite Point Field Well #: GP 31-14RD2 Hilcorp Alaska. LLC Completed: 9/67 RKB to MWL = 105.9' PBTD = 10,178' TD = 10,191' MAX HOLE ANGLE = 27° @ 4,300' CASING DETAIL Size WT Grade Conn ID Top Btm 20" 1 320' 2.75 Otis Ball Valve, w/ 1.5" ID thru ball. Surf 618' 13-3/8" 61 K-55 STC 12.515 Surf 2,328' 9-5/8" 40 N-80 LTC 8.835 Surf 4,783' 2 23 N-80 STC 6.366 Surf 3,693' 3-1/2" Camco KBM , Side Pocket Mandrels 26 P-110 LTC 6.276 3,693' 4,693' C-5 23 N-80 Seal Lock 6.366 4,693' 6,317' 7„ 23 N-80 LTC 6.366 6,317' 8,733' 5 29 N-80 LTC 6.184 8,733' 9,108' C-6 29 P-110 X -line 6.184 9108' 10,191' TUBING DETAIL 3-1/2" 1 9.2 1 L-80 BTC 2.992 1 38' 1 9,716' JEWELRY DETAIL No Depth ID Item Btm(TVD) Amount Condition Tubing hanger. 1 320' 2.75 Otis Ball Valve, w/ 1.5" ID thru ball. 1 2,251' 6,910' 3-1/2" Camco KBM , Side Pocket Mandrels 9,110' 3,760' 8,646' 3-1/2" Camco KBM , Side Pocket Mandrels Cmt Sqzd 4,775' 9,140' 3-1/2" Camco KBM , Side Pocket Mandrels 8,675' 5,672' 20 3-1/2" Camco KBM , Side Pocket Mandrels 2 6,360' 9,185' 3-1/2" Camco KBM , Side Pocket Mandrels 8,719' 6,921' Open f/ Prod. 3-1/2" Camco KBM , Side Pocket Mandrels 9,445' 7,578' 8,974' 3-1/2" Camco KBM , Side Pocket Mandrels 155 8,083' C-5 3-1/2" Camco KBM , Side Pocket Mandrels 9,725' 8,584' 9,247' 3-1/2" Camco KBM , Side Pocket Mandrels 3 9,057' 2.78 Otis Model "RH" Retrievable Pkr. 4 9,681' 2.635 Otis "Q" No -Go Profile Nipple, 2.75 5 9,716' 2.992 Ball Catcher Sub PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount Condition 1,265- 9,084' 9,085' 8,620' 8,621' 1 Cmt Sqzd 6,910' 9,109' 9,110' 8,645' 8,646' 1 Cmt Sqzd 9,140' 9,160' 8,675' 8,695' 20 Open f/ Prod. C 2 9,165' 9,185' 8,699' 8,719' 20 Open f/ Prod. C-3 9,445' 9,600' 8,974' 9,125' 155 Open f/ Prod. C-5 9,680' 9,725' 9,203' 9,247' 45 Open f/ Prod. 9,781' 9,782' 9,302' 9,302' 1 Cmt Sqzd 9,807' 9,837' 9,327' 9,356' 30 Open f/ Prod. C-6 9,880' 9,910' 9,398' 9,427' 30 Open f/ Prod. 9,940' 9,974' 9,457' 9,490' 34 Open f/ Prod. 9,980' 10,152' 9,496' 9,664' 172 Open f/ Prod. C 7 10,180' 10,190' 9,692' 9,701' 30 Covered w/ Fill AD -2 STOP / SPACER PIPE DETAIL No Top(WLM) Btm(WLM) Top(RKB) Btm(RKB) 1 1,147' 1,223' 1,189' 1,265- 2 5,618' 5,644' 5,660' 5,686- 3 6,868' 6,894' 6,910' 6,936' WIRELINE PROBLEMS Worked 2.25" GR through GLM 10/8/96 @ 3780' WLM 2.25" IB impression of a damaged latch or RS 10/8/96 @ 4779' WLM 2.3" Tapered Swedge, knocked GLV back into pocket10/25/96 @ 4779' WLM Fill Tagged w/ 2.30" Tapered Swedge 10/25/96 @ 10,090' WLM Revised By TDF 10/11/2012 Proposed Granite Point Field Well #: GP 31-141RD2 Ililcoru Ala+ku. LLf, Completed: 9/67 RKB to MWL= 105.9' • 1 T 20 Fatch 14 1 zz�: rr,I^ 13-3/8" Fa,�ft 561 °tt t� 644ft %1D 2 Farr 6.666ft L, 6 694E MD TOC @ 8,2 (temp log) EOT @ 9,716' 5 4 3 C-2 C-2 C-3 C-5 C-6 ✓ C-6 C-6 C-6 C-7 C-7 PBTD = 10,178' TD = 10,191' MAX HOLE ANGLE = 27° @ 4,300' CASING DETAIL Size WT Grade Conn ID Top Btm 20" 1 320' 2.75 Otis Ball Valve, w/ 1.5" ID thru ball. Surf 618' 13-3/8" 61 K-55 STC 12.515 Surf 2,328' 9-5/8" 40 N-80 LTC 8.835 Surf 4,783' 2 23 N-80 STC 6.366 Surf 31693' 3-1/2" Camco KBM , Side Pocket Mandrels 26 P-110 LTC 6.276 3,693' 4,693' C-5 23 N-80 Seal Lock 6.366 4,693' 6,317' 7" 23 N-80 LTC 6.366 6,317' 8,733' 5 29 N-80 LTC 6.184 8,733' 9,108' 29 P-110 X -line 6.184 9108' 10,191' TUBING DETAIL 3-1/2" 1 9.2 1 L-80 I BTC 1 2.992 1 38' 9,716' JEWELRY DETAIL No Depth ID Item Btm(TVD) Amount Condition Tubing hanger. 1 320' 2.75 Otis Ball Valve, w/ 1.5" ID thru ball. 1 2,251' 3-1/2" Camco KBM , Side Pocket Mandrels 9,110' 3,760' 8,646' 3-1/2" Camco KBM , Side Pocket Mandrels Cmt Sqzd 4,775' 9,140' 3-1/2" Camco KBM , Side Pocket Mandrels 8,675' 5,672' 20 3-1/2" Camco KBM , Side Pocket Mandrels 2 6,360' 9,185' 3-1/2" Camco KBM , Side Pocket Mandrels 8,719' 6,921' Open f/ Prod. 3-1/2" Camco KBM , Side Pocket Mandrels 9,445' 7,578 8,974' 3-1/2" Camco KBM , Side Pocket Mandrels 155 8,083' C-5 3-1/2" Camco KBM , Side Pocket Mandrels 9,725' 8,584' 9,247' 3-1/2" Camco KBM , Side Pocket Mandrels 3 9,057' 2.78 Otis Model "RH" Retrievable Pkr. 4 9,681' 2.635 Otis "Q" No -Go Profile Nipple, 2.75 5 9,716' 2.992 Ball Catcher Sub PEKFUKAIIUN DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount Condition 6,894' 9,084' 9,085' 8,620' 8,621' 1 Cmt Sqzd 9,109' 9,110' 8,645' 8,646' 1 Cmt Sqzd 9,140' 9,160' 8,675' 8,695' 20 Open f/ Prod. C-2 9,165' 9,185' 8,699' 8,719' 20 Open f/ Prod. C-3 9,445' 9,600' 8,974' 9,125' 155 Open f/ Prod. C-5 9,680' 9,725' 9,203' 9,247' 45 Open f/ Prod. C-6 ±9,757' ±9,777' ±9,278' 9,298' ±20' Future 9,781' 9,782' 9,302' 9,302' 1 Cmt Sqzd 9,807' 9,837' 9,327' 9,356' 30 Open f/ Prod. C-6 9,880' 9,910' 9,398' 9,427' 30 Open f/ Prod. 9,940' 9,974' 9,457' 9,490' 34 Open f/ Prod. 9,980' 10,152' 9,496' 9,664' 172 Open f/ Prod. C-7 10,180' 10,190' 9,692' 9,701' 10 Covered w/ Fill AD -2 STOP / SPACER PIPE DETAIL No Top(WLM) Btm(WLM) 1 1,147' 1,223' 2 5,618' 5,644' 3 6,868' 6,894' WIRELINE PROBLEMS Worked 2.25" GR through GLM 10/8/96 @ 3780' WLM 2.25" IB impression of a damaged latch or RS 10/8/96 @ 4779' WLM 2.3" Tapered Swedge, knocked GLV back into pocket10/25/96 @ 4779' WLM Fill Tagged w/ 2.30" Tapered Swedge 10/25/96 @ 10,090' WLM Revised By DT 06/14/14 Wireline Pressure Control Certification Level 2 - 10K Line % Stuffing I Packol Grease Injec Control Hea Gall check va Head Catchei Lubric Tool l STATE OF ALASKA ALSA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations Perforate U Other Patches Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re-enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 121 Stratigraphic ❑ Exploratory ❑ Service ❑ "' 100-266 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, Alaska 99504 50-733-10061-02 7. Property Designation (Lease Number): 8. Well Name and Number: R ADL0018761 Granite Pt St 31-14RD2 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Granite Point Field / Middle Kenai Oil 11. Present Well Condition Summary: Total Depth measured 10,191 feet Plugs measured 10,178 feet true vertical 9,700 feet Junk measured 10,090 (fill) feet Effective Depth measured 10,090 feet Packer measured 9,057 feet true vertical 9,604 feet true vertical 8,594 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 618' 20" 618' 618' Surface 2,328' 13-3/8" 2,328' 2,221' 3,090 psi 1,540 psi Intermediate 4,783' 9-5/8" 4,783' 4,459' 5,750 psi 3,090 psi Production 10,191' 7" 10,191' 9,702' 6,340 psi 3,830 psi Liner RECEIVED Perforation depth Measured depth (See Attached Schematic) OCT 12 2012 True Vertical depth (See Attached Schematic) GCC Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / L-80 9,716' MD 9,238' TVD Otis RH 9,057' MD Otis 320' MD Packers and SSSV (type, measured and true vertical depth) Retrievable Packer 8,594' TVD Ball Valve 320' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A JAN 2 8 2013, SCANNED 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 90 90 Subsequent to operation: 2 40 70 800 80 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development " Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas El WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Chad Helgeson, Operations Engineer Phone: 907-777-8405 Email chelgeson hilcoro.com Printed Name Stan Golis Title Operations Manager Signature U",— y Phone 907-777-8356 Date 17_ •�, ,5 OCT 16 Form 10-404 10-404 Revised 10/2012 1 �[ i' Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 31-14RD2 50-733-10061-02 100-266 1 8/29/12 9/9/12 08/29/2012 - Tuesday Attempting to run pack off across leaking #6 GLM, troubleshooting different tools to get past #3 GLM. Set Ad -2 bottom stop for #6 GLM pack off at 6,894" RKB utilizing 4' prong to get past #3 GLM. Attempted to set D&D pack off, could not get past #3 GLM. 08/30/2012 - Wednesday Attempting to set segments of pack off across #6 GLM. Set Weatherford pack off @ 6,892" WLM. Ran pipe between tubing and pack off @ 6,878' WLM and set. Attempted to run AA stop to complete pack off assembly across #6 GLM, could not get past #3 GLM @ 4,737' WLM with 4' of stem between centralizer and GS tool. 08/31/2012 - Thursday WL on well 31-14. Set pack off across #6 GLM @ 6,921' RKB. Pack off element 23' from 6,908' to 6,936' RKB. Set pack off across #4 GLM at 5,672' RKB. Pack off element 23' from 5,658' RKB to 5,686' RKB. 09/01/2012 - Friday WL set top pack off assembly in well 31-14RD2. 09/03/2012 - Sunday WL work on Well 31-14RD2. Pulled upper pack off assembly from 1,139' WLM down to 1,166' WLM. Ran ponytail to try and confirm tubing hole location(s) so we can run pack off in the correct place. Located hole @ 1,152' WLM and 1,216' WLM. 9/9/2012 - Saturday RU on 31-14RD. Move unit across the platform. PT rig up AD -2 stop. RIH. Could not get to shear. Ran several times with different shear pin. Finally got set. RIH with D&D. Pack off set @ 1,263' RKB. RIH with 35' spacer @ 1,261' RKB. RIH with next 35' spacer and a pack off on top 1,226' RKB. RIH with hold down, stop @ 1,189' RKB. Rig down and clean up area. Ililcorp Alaeku, LLC 20' 13 EO RKB to MWL = 105.9' PBTD = 10,178' TD = 10,191' MAX HOLE ANGLE = 27° @ 4,300' �r • SCHEMATIC CASING DETAIL Granite Point Field Well #: GP 31-14RD2 Completed: 9/67 Size WT Grade Conn ID Top Btm 20" 1 320' 2.75 Otis Ball Valve, w/ 1.5" ID thru ball. Surf 618' 13-3/8" 61 K-55 STC 12.515 Surf 2,328' 9-5/8" 40 N-80 LTC 8.835 Surf 4,783' 2 5 23 N-80 STC 6.366 Surf 3,693' 3-1/2" Camco KBM, Side Pocket Mandrels 26 P-110 LTC 6.276 3,693' 4,693' C-5 23 N-80 Seal Lock 6.366 4,693' 6,317' 7" 23 N-80 LTC 6.366 6,317' 8,733' 5 29 N-80 LTC 6.184 8,733' 9,108' C-6 29 P-110 Vine 6.184 9108' 10,191' TUBING DETAIL 3-1/2" 1 9.2 1 L-80 BTC 2.992 1 38' 1 9,716' JEWELRY DETAIL No Depth ID Item Btm(TVD) Amount Condition Tubing hanger. 1 320' 2.75 Otis Ball Valve, w/ 1.5" ID thru ball. 1 2,251' 3-1/2" Camco KBM, Side Pocket Mandrels 7- 3,760' 8,646' 3-1/2" Camco KBM, Side Pocket Mandrels 3 4,775' 9,140' 3-1/2" Camco KBM, Side Pocket Mandrels 'A 5,672' 20 3-1/2" Camco KBM, Side Pocket Mandrels 2 5 6,360' 9,185' 3-1/2" Camco KBM, Side Pocket Mandrels 6 6,921' Open f/ Prod. 3-1/2" Camco KBM, Side Pocket Mandrels 7 7,578' 8,974' 3-1/2" Camco KBM, Side Pocket Mandrels 155 8,083' C-5 3-1/2" Camco KBM , Side Pocket Mandrels 9,725' 8,584' 9,247' 3-1/2" Camco KBM , Side Pocket Mandrels 3 9,057' 2.78 Otis Model "RH" Retrievable Pkr. 4 9,681' 2.635 Otis "Q" No -Go Profile Nipple, 2.75 5 9,716' 2.992 Ball Catcher Sub PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amount Condition @ 10,090' WLM 9,084' 9,085' 8,620' 8,621' 1 Cmt Sqzd 9,109' 9,110' 8,645' 8,646' 1 Cmt Sqzd 9,140' 9,160' 8,675' 8,695' 20 Open f/ Prod. C-2 9,165' 9,185' 8,699' 8,719' 20 Open f/ Prod. C-3 9,445' 9,600' 8,974' 9,125' 155 Open f/ Prod. C-5 9,680' 9,725' 9,203' 9,247' 45 Open f/ Prod. 9,781' 9,782' 9,302' 9,302' 1 Cmt Sqzd 9,807' 9,837' 9,327' 9,356' 30 Open f/ Prod. C-6 9,880' 9,910' 9,398' 9,427' 30 Open f/ Prod. 9,940' 9,974' 9,457' 9,490' 34 Open f/ Prod. 9,980' 10,152' 9,496' 9,664' 172 Open f/ Prod. C 7 10,180' 10,190' 9,692' 9,701' 10 Covered w/ Fill AD -2 STOP / SPACER PIPE DETAIL No Top(WLM) Btm(WLM) Top(RKB) Btm(RKB) 1 1,147' 1,223' 1,189' 1,265' 2 5,630' 5,642' 5,672' 5,684' WIRELINE PROBLEMS Worked 2.25" GR through GLM 10/8/96 @ 3780' WLM 2.25" IB impression of a damaged latch or RS 10/8/96 @ 4779' WLM 2.3" Tapered Swedge, knocked GLV back into pocketl0/25/96 @ 4779' WLM Fill Tagged w/ 2.30" Tapered Swedge 10/25/96 @ 10,090' WLM Revised By TDF 10/11/2012 2011 April's GPP 44-11 Monitorineport • Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp@chevron.com] Sent: Wednesday, May 11, 2011 5:13 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Lambert, Steve A Subject: 2011 April's GPP 44-11 Monitoring Report Attachments: Master Well List TIO Report 2011 04 30.xls Hi Tom & Jim, Here is April 's GPP 44-11 monthly pressure report based on DIO #10, Rule #4 requiring daily pressures be taken on three wells and reported monthly on the 10-406 injection report. The attempt to flow GPP31-14RD2 has ended. The additional produced water (practically no oil) put too much strain on the 44-11 disposal well, so the 31-14RD2 well was shut-in and its pressures responded as expected. k©o - a c0 c,0 The GPP 44-11 well is still in full winter use and the pressures and volumes look appropriate. Bottom line, I don't see any indication that the ongoing batch injections into GPP 44-11 have affected the pressures in either of the other two wells. Larry Qt- C"5c- <<Master Well List TIO Report 2011 04 30.xls>> _Q;,;� V-� 5/16/2011 Plot Press & Rate vs Time - Well GP 31-14RD2 800 700 7.. -9 5/8" y 133/8" 20" 600 Tubing 500 v 3 .400 v CL VW L� 300 r 200 100 - 0 «--._ ......_ 0 0 0 n rn m Q N N f"I V p O O Date 7" 9 5/8" 13 3/8" 20" 10% 04/30/11 60 310 355 4 55 04/29/11 60 310 360 4 60 04/28/11 60 305 355 4 60 04/27/11 65 310 355 4 60 04/26/11 65 310 355 3 60 04/25/11 65 310 355 0 65 04/24/11 65 310 355 0 65 04/23/11 65 320 360 0 65 04/22/11 65 310 355 4 65 04/21/11 65 310 355 4 65 04/20/11 65 310 360 5 65 04/19/11 75 320 365 5 80 04/18/11 ' 350 325 370 5 80 04/17/11 350 325 370 5 80 04/16/11 350 325 370 5 80 04/15/11 350 330 370 4 80 04/14/11 350 330 370 4 80 04/13/11 350 330 370 4 80 04/12/11 360 340 330 4 90 04/11/11 360 340 330 4 90 04/10/11 360 340 330 4 90 04/09/11 360 340 330 4 100 04/08/11 360 340 330 4 190 04/07/11 360 340 330 4 85 04/06/11 360 340 330 4 80 04/05/11 370 340 330 4 90 04/04/11 370 330 370 4 90 04/03/11 360 330 370 5 85 04/02/11 370 330 370 4 85 04/01/11 340 330 370 3 90 03/31/11 375 325 370 3 90 03/30/11 370 330, 370 4 90 03/29/11 370 3301 370 4 95 03/28/11 380 3301 375 5 100 03/27/11 380 330 375 5 85 03/26/11 ..,OO=ZQIL 330 375 5 250 5/16/2011 11:18 AM - TIO Reports 7e.xls J J Dolan TIO Report Data Sheet GP 31-14RD2 GAS LIFT Permit # 1002660 Sundry # 398-200 API # 50-733-10061-02 10/30/2010 to 04/30/2011 Master Well List TIO Report 2011 04 30 (5).xls GP 31-14RD2 • • OT ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS333 W. 7th AVENUE, SUITE 100 CONSERVATION CO110IISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Chris Myers Field Superintendent Union Oil Company of California PO Box 196247 Anchorage, Alaska 99519 RE: No -Flow Verification Granite Point State 31-14RD2 Granite Point Field PTD 1002660 Dear Mr. Myers: March 29, 2011 A-eow 1� � b ZV On March 24, 2011 an Alaska Oil and Gas Conservation Commission (Commission) Petroleum Inspector witnessed a "no flow test" of Granite Point State 31-14RD2 located on the Granite Point Platform in Cook Inlet. The well is operated by Union Oil Company of California (Union). A subsurface safety valve is not required to be installed in this well based on the no -flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. Granite Point State 31-14RD2 is a shut in well that Union intends to restart production. The Commission Inspector confirmed that Union verified no obstruction exists in the wellbore. There was no tubing pressure build-up observed during a 1.5 hour monitoring periods while the well was shut in. Granite Point State 31-14RD2 was then monitored an additional 1.5 hours for flow by opening it to atmosphere through flow measurement equipment with suitable range and accuracy. During the flow monitoring period, no recordable gas flow rate was measured on the calibrated flow meter. The subsurface safety valve must be returned to service if Granite Point State 31-14RD2 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Granite Point Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 7 131 f P. I. Supervisor FROM: John Crisp, Petroleum Inspector DATE: March 24, 2011 SUBJECT: No Flow Test Granite Point Platform Well 31-14RD2 PTD # 1002660 March 24, 2011: I traveled to Union Oil Company of California's Granite Point Platform to witness SVS tests & to witness AOGCC witness required no flow test on 31-14RD2. When I arrived on the Platform I witnessed well 31-14RD2 rigged up with no flow equipment required by AOGCC Guidance Bulletin 10-004 Appendix A — No flow test equipment. No flow of gas or liquid could be seen from temporary flow hose taken to a 55 gal. drum witnessed for 1 Y2 hour. Well was shut in for 1 Y2 hour to observe tubing pressure build up. No pressure build up occurred in the 1 Y2 hour shut in period. Well 31-14RD2 was then opened up to 5 gal. pail of water to �. observe possible gas flow. Slight bubbling was observed in the 5 gal. pail of water but no flow could be measured with Armor flow methane flow meter S/N 991632 calibrated 05/2010. This flow test was witnessed for 1 hour. Summary: Successful No Flow performed & witnessed on GPP well 31-14 RD2 as per no flow test procedure & equipment arraignment (20 AAC 25.265 k) Attachments: none. Non -Confidential No flow test GPP 31-14 RD2 03-24-11 Regg, James B (DOA) i 0 From: Regg, James B (DOA) Sent: Friday, March 25, 2011 4:01 PM To: 'askinm@chevron.com' Cc: Crisp, John H (DOA) Subject: GP Platform 31-14RD2 No Flow have reviewed the Commission Inpector's witnessed no -flow test report and concur with the findings. Union is authorized to bring GP State 31-14RD2 on line without a subsurface safety valve based on the results of the no flow test. A formal letter will be provided to Mr. Chris Myers next week. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 3/25/2011 Page 1 of 1 August 3, 2009 Dale A. Haines Union Oil Company of California Manager, Oil & Gas 3800 Centerpoint Drive, .Suite 100 Operations Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com SCANNED APP 0 12014 Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less them from years); and {3) removed from porn fist SCU 312-09 (nets in OpenMione Shutd"n status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, (� 'e, 1I Dale Haines Alaska Area Operations Manager (I DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 1442 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 16-42 1670770 Feb -87 Abandoned No Flow Phase I Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Coll sed Casing 100% water production Phase I Abandon abandon at end of platform life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 1 Dec-00ITubing-to-casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D40K 1820830 1 Sep -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of latform life v-2SttL 1!,,,n ,n Se U2 h -Line wire In LJ. LOW 011 roduction trom LS. PnaSe 1 Abandon abandon at end of lattorm lite G_7.4 176n i7n MA,_aI Nn t-nnwn damaOP. 14ivh Water Cut Phace I Ahandnn ahandnn at end of nlatfnrm lift G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life iia -31 I IY31YYU I VeC-YY I NO Known damage I Produced water I Phase I Abandon I abandon at end of platform life Di-2RD 1 1750070 1 Dec -02 No known damage IPlatform shut-in -- uneconomic jPhase I Abandon abandon at end of platform life I Ili -'t I 16707Rn I i)p.r.-n71Nn Icnna damave IPlatfnrm chnt-in __ nnernn.mic Ph.— T Ahandnn ah—Ano at a.,A . fA.tf .,.. lif i Di -4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in — uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 13-4 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -0I no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug -9 parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21A-4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date iCU 2113-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 2313-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov-0no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek as 2011-2014 SCU 3213-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-R 1610430 Jan -9 no known damage no flow Pnssihle P&A 7010-7013 SCU 4113-9 1 1002690 Nov -9j no known damage 1 no flo I Possible WO for Tyonek gas 2011-2014 ACii xi_g I 1(.7n -i1 n Mo—Q9 nnn hM hnlr in tho I hiah water I Pn ihla PR, A 7n1 n -7n14 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 ;RU 212-10 1600180 Oct -91 1 no known damage high water Possible Beluga gas 2010-2013 ;RU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 ;RU 234-15 1600410 Dec -0 no known damage no flow Possible shallow gas or gas storage 2011-2014 onopod A-10 1670760 Apr -8, Collapsed casin Producing Coal Phase I Abandon abandon at end of platform life onopod A-23 1 1720200 Jun -81 Collapsed casin Producing Coal Phase I Abandon abandon at end of platform life onopod A-30 1 1730140 Oct -91 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of platform life C ALASKA OIL AND GALS June 22, 2009 SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dale Haines UNOCAL S(',pNNED SPR 0 12014 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubertnalaska.gov. Sincerely, Cathy . Foerster Commissioner Enclosure 0 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 Union Oil Company of California 162-031 Soldotna Ck Unit 43-09 Union Oil Company of California fi 174-066 Soldotna Ck Unit 44-04 Union Oil Company ofCalifo inr a 160-018 Swanson Riv Unit 212-10 Union Oil Company of California 161-033 ;Swanson Riv Unit 212-27 Union Oil Company of California 160-041 Swanson Riv Unit 234-15 Union Oil Company of California 167-076 Trading Bay St A-10 _ Union Oil Company of California 1 172-020 (Trading Bay St A-23DPN - Union Oil Company of California 173-014 1 Trading Bay St A-30 (R5 vetcogray Vetco Gray Canada Inc. VGSC 13.08.08 Revision: A Canadian Running & Maintenance Specification Date: 17 Oct 01 Page: 1 of 9 Running Procedure — VGCT-3 Coiled Tubing System SCOPE The intent of this specification is to detail the field service procedures related to the installation and retrieval of type VGCTM-3 mandrel hanger. The intent of this document is to compliment good coiled tubing practices and procedures. In the event of a conflict between coiled tubing operating procedures and this document, defer to the coiled tubing practices. 2 DISCLAIMER This specification is the property of Vetco Gray Canada Inc. and is intended to be used by Vetco Gray Canada technicians in equipment servicing. Vetco Gray Canada Inc. is pleased to provide other parties with copies of the specifications on request, subject to confidentiality restrictions by the recipient and retention of ownership by Vetco Gray Canada Inc. A copy is furnished to other parties on an advisory basis only and Vetco Gray Canada Inc. does not assume any liability, nor does it make any warranty, express or implied, as a result of furnishing the information or use of the specification by other parties. TECHNICAL DESCRIPTION 3.1 The type VGCTM-3 mandrel hanger is multi -piece hanger. The top of the hanger is internally machined to accept a Baker GS running tool. The bottom of the hanger is internally threaded to mate with a coiled tubing connector. The hanger may come with or without a back pressure valve preparation. If the mandrel hanger is supplied with the back pressure valve preparation the hanger cannot be landed with the back pressure valve installed as this will interfere with the functionality of the GS tool. The isolation seals, a compression seal assembly, are mechanically energized by an upper bank of lock screws and located on the OD of the hanger. See Figure 1. 3.2 The mandrel hanger has a locating shoulder above compression seal assembly. This shoulder locates to the matching shoulder in the head to locate the hanger while engaging the lower bank of lock screws in the tubing head. The tubular load is supported by the lock screws. The locating shoulder is not designed to support full string weight or a pressure test from above or below the tubing hanger. 3.3 In the middle of the hanger there is a 45 -degree beveled groove, which accommodates the noses of the lock screws to engage the compression seal assembly. At the bottom of the tubing hanger is another groove which accomodates the lock screws which support tubular and pressure loads placed on the hanger. W PREPARED: J. Rakowski REVIEWED: T. Araujo APPROVED: L. Boisvert DATE: 1 18 October 01 DATE: 1 19 October 01 1 DATE: 22 October 01 CRM 13.08.08 1 Revision: A Date: 18 October, 01 1 Page: 2 of 9 4 SPECIFICATIONS 4.1 Refer to specific drawing number of the mandrel hanger being installed for spare parts and dimensions. TOOLS REQUIRED 5.1 5/8 wrench 5.2 24" crescent wrench 5.3 (2) 24-36" pipe wrenches 5.4 pipe cutter 5.5 tape measure 5.6 plastic injection pump with grease port attachment & bleeder tool. LOCATING 1PPER BANK .00K SCREW TONGING AREA BANK ( ^ SCREW � LOCATING SHOULDER LOCK SCREW SURE SHOULDER (READ \ FOR ENERGIZING kD Figure 1 — VGCTH-3 TUBING HEAD AND VGCTM-3 HANGER COMPRESSION SEAL ASSEMBLY CRM 13.08.08 1 Revision: A I Date: 18 October, 01 Pa e: 3 of 9 6 PRE -OPERATIONAL CHECKS 6.1 Verify the type and model of the hanger matches the top profile of the head. Test the fit of the hanger in the head. 6.2 Record part number, serial number, heat number and material designation. 6.3 Clean the OD and ID of the hanger with solvent and wipe dry. Verify that the threaded connections are of the correct size and type for the coiled tubing connector. Also making sure that the coiled tubing connector is the proper size for the tubing being run. 6.4 Check that the hanger or seal elements have not been damaged during shipping. Note: If seal elements have been damaged or need to be replaced. Please refer to dwg # C220213 in Appendix A of this specification for the procedure. 6.5 Verify the GS lift profile accepts the running tool being used. Verify the tool will drift the valves used. 6.6 The coil tubing hanger should be drifted through the tree & landed in the coil tubing head spool before field installation of the assembly. 6.7 Ensure the spacer spool is large enough to fit the coiled tubing connector, hanger, and GS fishing tool. 6.8 With appropriate measuring device, measure from the top of the VGCTH-3 coiled tubing head to the bottom of spacer spool (See Figure 2). Record this measurement. 6.9 Recommend the use of a tubing straightener to the coiled tubing company. This will minimize risk of damage to the tubing head seal bore from wear (as detailed in 7.14) CRM 13.08.08 1 Revision: A I Date: 18 October, 01 Pa e: 4 of 9 /,-INJECTOR -PACKOFF FLANGE ACER SPOOL ANNULAR BOP ,-RAM BOP L TUBING HEAD Figure 2 - Equipment Layout CRM 13.08.08 1 Revision: A I Date: 18 October, 01 1 Page: 5 of 9 7 INSTALLATION OF MANDREL HANGER 7.1 Rig up the coiled tubing unit. 7.2 Ensure the lock screws are fully retracted in VGCTH-3 tubing head. 7.3 Fully open all vertical valves below the BOP stack as per applicable procedures. 7.4 Run tubing to desired depth (with annular BOP closed) minus the measured distance between the top of the tubing head and bottom of the spool. Lubricate the coil while running to reduce wear on the tubing head. 7.5 Close slip and pipe rams onto coiled tubing as per applicable procedure. 7.6 Break connection between top of BOP and spacer spool. Walk injector up to allow access. 7.7 Install safety clamp and C -plate. Cut pipe and install tubing connector. 7.8 Apply pipe dope to pin connection on tubing connector and install VGCTM-3 mandrel hanger. Torque as required. Due to possible damage to the sealing areas of the hanger DO NOT place the wrench on the hanger seal areas. Apply clean grease to the OD of the hanger. Orient the split on the lockscrew load shoulder of the tubing hanger such that it does not align with the lock screws (upper compression packing lock screws are 900 apart so the split should be oriented 450 to the lockscrew). 7.9 Measure the distance from the top of the BOP to the top of the hanger and record. 7.10 Once the hanger has been installed on the string, install the GS running tool as per applicable procedures. Engage running tool in top of hanger and pull test as required against slip rams. Remove safety clamp and make up riser to BOP. 7.11 Retract slip rams and pipe rams in BOP as per applicable procedures. Ensure that all rams are fully retracted. Calculate the distance from the top of the VGCTH-3 tubing head to the top of the VGCTM-3 hanger. Slowly lower the hanger into the bowl with the running tool. Keep track of the location of the hanger by measuring the running tool and tubing as it is lowered. Once the top of the hanger is 5 to 6 inches above the top of the head, the locating shoulder on the hanger will be 2 to 3 inches above the locating shoulder in the tubing head. From this point, lower the hanger very slowly until the weight starts to drop on the weight indicator. This must be done carefully as the locating shoulder WILL NOT support the entire string weight. No more than 10,000 lbs should be applied to the locating shoulder. DO NOT DISENGAGE THE RUNNING TOOL. 7.12 Once the hanger is properly set in the top bowl of the head run in the lower bank of lock screws. Torque to approximately 20 ft -lbs (use a 6" wrench and only one hand). Do not over -torque as this will deform the hanger. Verify that all gland nuts are tight. 7.13 Pull test the hanger to 10,000 lbs over string weight. If any motion of the hanger is detected, repeat step 7.12. CRM 13.08.08 1 Revision: A I Date. 18 October, 01 1 Page: 6 of 9 7.14 Tighten the upper bank of lock screws; use a circular pattern turning each lock screw in one turn and then switching to the next lock screw; care should be taken to ensure the lockscrews are engaged evenly. Torque to approximately 20 ft -lbs (use a 6" wrench and only one hand). Verify seal integrity by pressure testing through the test ports in the tubing head (see Figure 3). If this test fails, continue to torque lock screws and repeat pressure test. If this fails as well, retract the lock screws and run the hanger back to surface. Redress the seals and repeat steps 7.9 to 7.13. If the seal still fails the test ports may be used as contingency plastic injection ports to pump plastic between the compression seals. This will only need to be done if the tubing or wire line run through the head damages the seal bore or the seals were damaged when running the hanger through the stack. Care should be taken to centralize tubing and wire line run through VGCTH-3 heads to minimize damage as the seal bore is the smallest bore in the head and will take wear first. The plastic may or may not energize the seal elements, after which the seals should be tested from above the VGCTM-3 hanger. 7.15 Release running tool and retract. 7.16 Rig down. TE Figure 3 - VGCTH HEAD WITH VGCTM HANGER INSTALLED CRM 13.08.08 Revision: A Date: 18 October, 01 Page: 7 of 9 8 RECOVERY 8.1 Rig up the coiled tubing unit. 8.2 Install GS running tool on tubing. 8.3 Ensure all valves are fully open and BOP rams are fully retracted. 8.4 Run tool into hanger and engage. Pull test to string weight to ensure tool is set. 8.5 Set tension to equal string weight. 8.6 Fully retract both banks of lockscrews. 8.7 Pull tubing until GS running tool, hanger, and coiled tubing adapter are above the top of the ram BOP with enough tubing sticking up to feed into injector (or leave 12" stickup & use internal coiled tubing connector to attach to tubing in injector). 8.8 Close slip rams. Remove GS running tool, hanger, and coil tubing adapter. Lower injector onto coil tubing stub and walk down. 8.9 Run tubing out of the well. 8.10 Close valves and rig down. 9 POST OPERATIONAL MAINTENANCE On site maintenance is minimal for this equipment. Return to the nearest ABB. Vetco Gray facility. CRM 13.08.08 1 Revision: A I Date: 18 October, 01 1 Page: 8 of 9 APPENDIX A CRM 13.08.08 Revision: A Date: ]8October, 0] Page: 9 of 9 : 2 \ §/\ a\\ :k § _� $$ ) 2 ( ■�}� ~ \ $( ; § ® OR — k § LLx ° 20§§§=§§ | -, k� \ \ ) { _ ) | # k}\ § k § { ( ) ! \ 0 ®{§ \\ 2 ! §]. ( 2)a®G { k\ 0m [)0 tk a o, . -E \�[ ` Bqk s& \ /) kr)/� &� § S% \� C:L\ \k\)\ \/ ® \ §2 !° \0 kms {m « |kr ««««§ «« > EE) �� V)ee3E U) (1) @ n - \ k § k k ` » ------------------------------------ (} - TONYKNOWLES, GOVERNOR AILASKA OIL AND GAS 3001 PORCUPINE DRIVE ANCHORAGCONSERVATION COMMISSION PHONE: ) 90 279-1433 99501-3192 FAX: (907) 276-7542 December 6, 1999 Dan Williamson Drilling Manager UNOCAL P O Box 196247 Anchorage, Alaska 99519 Re: Permit ?Number Ltr Dated October 11, 1999 Dear Mr. Williamson: AOGCC history database had a problem with six duplicate permit numbers that occurred several years ago. The current listed well permits were not issued by AOGCC. We added a seventh digit to the permit number and inturn created a database problem. I corrected this situation by changing the permit number to a new Y2K seven -digit permit number. The new Y2K permit number (first six digits) should be annotated on all reports submitted to AOGCC for these named wells in the future: Current Permit Well name New Y2K Permit Number 66-0056-1 Granite Pt St 31-14RD 1 100-265-0 66-0056-2 Granite Pt St 31-14RD2 100-266-0 74-0026-1 Soldotna Ck Unit 32B-09 100-267-0 72-0017-1 Soldotna Ck Unit 33A-08 100-268-0 80-0107-1 Soldotna Ck Unit 41 B-09 100-269-0 68-0044-1 Trading Bay Unit G-12R.D 100-270-0 The permit number changes were made December 5, 1999 by AOGCC Sincerely, Steve McMains Statistical Technician ,., STATE OF ALASKA .,., ALASKA C.. AND GAS CONSERVATION __�OMMISSION R-a� APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: Convert To W. Injector 2. Name of Operator Plugs (measured) 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) 9700' Development: x 115' RKB above MSL feet 3. Address Effective depth: Exploratory: 10178' 7. Unit or Property name Junk (measured) ORIGNAL Stratigraphic: true vertical P.O. Box 196247 Anchorage, AK 99519 feet Service: Granite Point Field 4. Location of well at surface Leg # 1, Slot # 5 Length 8. Well number 2362' FNL. 1258' FWL, Sec. 13, T10N, R12W, SM Measured depth True vertical depth Structural 31-14RD2 At top of productive interval 9140' MD 9. Permit number 1448' FNL, 372' FEL, Sec. 14, T10N, R12W, SM Conductor 577' 66-0056-2 At effective depth 10178' MD 1200 sx 618' 10. API number 1485' FNL, 159' FEL, Sec. 14, T10N, R12W, SM 2286' 50- 733-10061-02 At total depth 2328' 2221' 11. Field/Pool 1485' FNL, 157' FEL, Sec. 14, T10N, R12W, SM 9-5/8' Granite Point Field 12. Present well condition summary Total depth: measured 10191' feet Plugs (measured) true vertical 9700' feet Effective depth: measured 10178' feet Junk (measured) ORIGNAL true vertical 9689' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 577' 20' 1200 sx 618' 618' Surface 2286' 13-3/8' 800 sx 2328' 2221' Intermediate 4740' 9-5/8' 500 sx 4783' 4459' Production 10191' 7' 216 sx 10191' 9700' Liner Perforation depth: measured 9140-9160', 9165-9185', 9445-9600', 9680-9725', 9807-983T, 9880-9910', 9940-9974', 9980-10075', 10042-10152', 10180-10190'. true vertical 8675-8694', 8699-8719', 8973-9125', 9203-9247', 9326-9356', 9398-942 t$;,' 9495-9539', 9556-9664'. F Tubing (size, grade, and measured depth) 3-1/2',9.2#, N-80 0 9716' MD ;;►� 241998 Packers and SSSV (type and measured depth) Otis 'RH' Packer 0 9857' MD & Otis ball valve 0 320' MDtt 13. Attachements Description summary of proposal: X Detailed operations program: X BOP s 14. Estimated date for commencing operation 15. Status of well classification as: August 20, 1998 16. If proposal well verbally approved: oil:.x Gas: Suspended: Name of approver Date approved Service: Request conversion to water injector. 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: 4 a" Dale Haines Title: Drilling Manager Date: 7/17/1998 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No.,� O Plug integrity BOP Test Location clearance Mechanical Integrity Test +� Subsequent form required 10- d 19� ,,�g� e6 ORIGINAL ORIGINAL SIGNED- BY i Robert N. Chlittaensm Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE UNOCAL Granite Point Field Well # 31-14 RD -2 Slickline Proposal Revised 7/14/98 Rev #1 Assembled by Steve Tyler Objectives: 1. Convert to an injector. a) Gage/Clean Tbg b) Replace GLV's w/ Dummy Valves c) Conduct an MIT. Wireline Problems: Possible damaged valve latch @ GLM #3, 4775' Tagged Fill @ 10,090' on 10/25/96 w/ 2.30" Tapered Swedge. Tubing Size: 3-1/2', 9.2#, N-80 Buttress Elevations WLR SSSV 320' Pir 9057' Otis "Q" Nipple 9681' Ball Catcher Sub (EOT) 9716' Minimum Y.D. WLR SSSV 2.75" @ 320' 15' thru Ball Valve 2.75 "Q" No -Go Nipple 2.639' @ 9,681 Deviation: Max 27° @ 4,300' Perforations: 9,085' WSO 9,110' Cmt Sqzd C-2 9,140'- 9,160' Open C-2 9,165' - 9,185' Open C-5 9,445' - 9,600' Open C-6 9,680' - 9,725' Open 9,782' Cmt Sqzd C-6 9,8071- 9,837 Open C-6 9,880'- 9,910' Open C-6 9,940'- 9,974' Open C-7 9,980' -10,152' Open C-7 10,180' -10,190' Open Slickline Procedure 31-14 RD2 I. Slickline Work [Gage tbg, Replace GLV's wl Dummys] 1. Hold Prejob safety meeting w/ applicable personnel. 2. RU slickline unit, BOP's and lubricator. Pressure test to 1500 psi. MU 2.5" gauge ring onto slickline tools string. 3. RI and tag fill. ( Last fill tagged on 10/25/96 w/ 2.3" Swedge @ 10,090' ) POH. 4. Break-out gauge ring. 5. MU KO & PT. RI retrieve GLV's 1 through 9. Replace with Dummy valves. U. Pressure Testing to Determine Tubular Integrity 1. Pressure test tbg/csg annulus to 2150 psi. Monitor tbg pressure. (may Have to remove GLV #1 to fill up annulus) 2. If csg pressure bleeds off, then RI w/ Slickline, set a plug in the "Q" nipple @ 9,681'. 3. Pressure test tbg to 3,000 psi. Monitor csg pressure. 4. Pressure test csg to 2100 psi. Monitor tbg pressure. Send results back to Anchorage. 5. Retrieve plug. RD Slickline. III. Conduct a Pressure MIT (Pending results from Pressure Testing) I. Advise Blair Wondzell at AOGCC of MIT at least 24 hours in advance of test. Phone number to reach him is- . This pwilll. allow sufficient time for inspector to make arrangement to witness test. 2. Rig upressure �recorders on Teo` th the tul5i ng and the tbg/csg annulus. (Only if AOGCC Rep is not on Location) 3. Record pretest conditions of the tubing and the tbg/csg annulus on the attached form. 4. Hold a prejob safety meeting with Production Forman, and Operators. 5. Pressure test all applicable surface equipment lines to 2,500 psi. 6. Isolate the tbg/csg annulus relief valve, if applicable, for the test. Pressure up with FTW on the tbg/csg annulus to a surface pressure greater than 2150 psi. Call Anchorage if this pressure cannot be obtained 7. Record each tubing pressure, the tbg/csg annulus pressure and time at the start of the test on the attached form. 8. After 15 minutes record each tubing and the tbgicsg annulus pressures, on the attached form. 9. After 30 minutes record each tubing and the tbg/csg annulus pressures, on the attached form. 10. Bleed down the tbg/csg annulus pressure. 11. If the pressure change for the 30 minute interval was less than 10% of the starting pressure and the pressure in the last 15 minutes of the test has either stabilized or is trending toward stabilization when compared to the change that occurred during the first 15 minute interval, both the..WtIar1CJrG 1De passed the integrity test. If test fails, call Anchorage. VU NOTE:If during test the well restablizes, then restart the test. 19�g Finish the attached form, sign and send to Anchorage for filing with AOGCC. tl�l �i aas UOAS4 NNW 04 w 4,71 EOT 4 G P 31-M RD. R KB to TBG Head =' PSTD = 10,178' TD = 10,191' MAX HOLE ANGLE = 27° 0 4,300' SIZE WT CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 20" 3780' WLM 9,109' Tubing hanger. 1. Surf 618' 13-3/8" 61.0 K-55 STC 12.515 Surf 2,328' 9-5/8" 40 N-80 LTC 8.835 Surf 4,783' 7" 23 N-80 STC 6.366 Surf 3,693' 7' 26 P-110 LTC 6.276 3,693' 4,693' 7" 23 N-80 Seal Lack 6.366 4,693' 6,317' 7" 23 N-80 LTC 6.366 6,317' 8,733' 7" 29 N-80 LTC 6.184 8,733' 9,108' 7" 29 P-110 X -tine 6.184 9108' 10,191' Tubing: 3-1/2" 9.2 L-80 BTC 2.992 38' 11,685' Zone PERFORATION DATA Top Btm Amount Condition JEWELRY DETAIL NO. Depth ID Item 3780' WLM 9,109' Tubing hanger. 1. 320' 2.75 Otis Ball Valve, w/ 1.5" ID thru ball. 2. 3-1/2" Cameo KBLM , Side Pocket Mandrels - GLM #1. 2251 9,185' GLM #2. 3760 9,445' GL,ri #3. 4775 C-6 GLIM #4. 5672 45 Open f/ Prod. GLIM #5. 6360 9,782' GLM #6. 6921 9,807' GLM #7. 7578 C-6 GLM #8. 8083 30 Open f/ Prod. GLIM #9. 8584 9,974' 3. 9857' 2.78 Otis Madel "RH" Retrievable Pkr. 4. 9681' 2.635 Otis "Q" No -Go Profile Nipple, 2.75 S. 9716' 2.992 Ball Catcher Sub Zone PERFORATION DATA Top Btm Amount Condition 9,084' 9,085' 1 Cmt Sqzd 3780' WLM 9,109' 9,110' 1 Cmt Sqzd C-2 9,140' 9,160' 20 Open f/ Prod. C-2 9,165' 9,185' 20 Open f/ Prod. C-5 9,445' 9,600' 155 Open f/ Prod. C-6 9,680' 9,725 45 Open f/ Prod. 9,781' 9,782' 1 Cmt Sqzd C-6 9,807' 9,837' 30 Open f/ Prod. C-6 9,880' 9,910' 30 Open f/ Prod. C16 9,940' 9,974' 34 Open f/ Prod. C-7 9,980' 10,152' 172 Open f/ Prod. C-7 10,180' 10,190' 10 Covered w/ FII WIRELINE PROBLEMS Worked 2.2S' GR through GLM 10/8/96 ® 3780' WLM 2.25" 1:B impression of a damaged latch or RS 10/8/96 O 4779' MM 2.3" Tapered Swedge, knocked GLV back into pocket 10/'-5/96 ® 4779' WLNI Fill Tagged w/ 230" Tapered Swedge 10/'.S/96 @ 10,090' WLM .: Unocal North Arne Oil 3 G33 OM:31an U;. -cat C, -cranan ,._. P 0. :cx'C-724: Ancro•ace- Alasxa ,9-9 I g-3= 47, Teieanore 19071 27o" oCCAU N n ICA In 76 Acril 16, 1990 Atasxa Region Alaska Oil & Gas Conser -ration Com`^..ission 3 001 Pore::: ine Dr. Anc:Zorage AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the '*Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil -operated Mononvd and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. GSB/lew Yours very tz-ul.y, Ga S. (_Bush .� Regional Drilling Manager i ApA 21; lois. GRANITE POINT PLATFORM FROM NW CORNER OF SECTION 13, T10N, R12W CONDUCTOR "Y" COOR. "X" COOK. WELL # FSL FEL Leg#l: 2,544,566.00 2639297.33 1 295449572.08 2639294.75 13-13 2371 1267 2 295449572.41 2639299.33 44-14 2373 1262 3 295449,569.75 263,302.99 33-14 & RD 2371 1258 4 2,5449565.34 263,303.99 31-23 2366 1256 5 2,5449561.34 2639302.08 31-14 & RD 2362 1258 1 & 2 6 21544,599.42 263,297.83 44-11 & RD 2360 1261 7 295449560.67 2639293.33 Open 8 2,5449564.50 263,290.83 12-24 2363 1269 9 2,5449569.00 2639291.42 32-23 & RDr2 2368 '1269 Leg;: 2: 215449610.00 263,364.00 r Compressors Legr3: 29544,543.33 2639408.00 1 —29544,548.16 2639403.42 31-13 2382 1370 2 29544,549.91 2639407.59 22-13 2379 1375 3 295449548.66 2639,412.00 MUC#I-1 2391 1379 4 295449544.99 263,414.41 MUC"I-2- 2386 1381 5 2,5449540.42 2639413.91 32-139 33-13 2390 1379 6 29544,537.25 263,410.58 24-13 & RD 2392 1376 7 2,544,537.00 263,406.09 42-23X, 31-23 2380 1371 8 2,5442539.58 2633,402.42 11-24 2383 1368 9 2,5449544.08 263,401.42 11-13 2379 1375 Leg:'4: 295449499.58 263,341.33 ;� r : ""' Form 10-403 Submit "intentions" In Triplicate • RFV. 1-10-73 f ;..01 & "Subsequent Reports" In Duplicate j STATE OF ALASKA 5. API NUMERICAL CODE OIL AND GAS CONSERVATION COMMITTEE. 50-133-10061 6. LEASE DESIGNATION AND SERIAL NO. SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT—" for such proposals.) ADL 18761 1. OILGAS 1 OTHER 7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELL WELLD 2. NAME OF OPERATOR a. UNIT, FARM OR LEASE NAM UNION OIL CO. OF CALIFORNIA UNIO - MOBIL STATE #1 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. BOX 6247 ANCHORAGE ALASKA 99502 GPS 31-14 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT At surface POINT 2362' S & 1258' E from N.W. corner, Sec. 13, TION,, -GRANITE 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) R12W, S.M. Leg #1 Conductor #5 Sec. 14, TIQN.-_402W. S.M. 13. ELEVATIONS (Show whether OF, RT, GR, etc.) - 12. PERMIT NO. KB 95' above MSL 66-56 14. Check Appropriate Box To .Indicate Nature of Notice, Report, or, Utner uata NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: TEST WATER SHUT-OFF PULL OR ALTER CASING WATER SHUT-OFF REPAIRING WELL FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING .SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) (Other) CHANGES OF OPERATOR (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. FROM: MOBIL OIL CORP. TO: UNION OIL CO. OF CALIFORNIA 16. 1 hereby certify that the foregoing Is true and correct 1'iE.CfIVCD SIGNED �' ! TITLE -DISTRICT DRILLING SUPT. _DATE .112317$ (This space`f_orSta office use) APPROVED BY 41Z2,_7 TITLE - — ` DATE CONDITIONS OF PPROVAL, 1 ANY: "PPI`c1'od CcJr.,_,. See Instructions On Reverse Side i. co 5228(9-ee) Mobil Oil Corporation WELL COMPLETION REPORT ORIGINAL DRILLING OPERATOR Mobil Oil Corporation WELL N0. Granite Point State 31-14 OH, RD#l, FIELD Granite Point SEC. 14 T. ION R. 12W S.M. B & M STATE Alaska COUNTY Kenai LOCATION From NW Corner Sec. 14, 2362.'E & 1258'E LAND OFFICE LEASE NO. ELEVATIONS 110' K. B. ) (MAT) ENGINEER ' GEOLOGIST J. Meyer & H. Hixson DATE 11/3/67 SIGNED TITLE C. C. Woodruff Area Engineer. - COMMENCED DRILLING 12-24-66 GEOLOGICAL MARKERS DEPTH COMPLETED DRILLING '8'24.-67 TOTAL DEPTH10,191(RW} 2)PLUGGED DEPTH JUNK _.See attached diagram for Redrill #1 ON PRODUCTION 9"9-67 FLOW ING1X&GXCDKk0MM .(CROSS OUT UNNECESSARY WORDS) PRODUCTION DATA PRODUCTION, CLEAN OIL GRAVITY TOTAL CUT BEAN SIZE TUBING CASING GAS CLEAN OIL % PRESSURE PRESSURE MCF PER DAY INITIAL B/D AFTER _DAYS 3088 e/D 41.0 0.3% 1124/64 272 774 1646 CASING RECORD (PRESENT HOLE) SIZE OF CASING(A.P.i.) DEPTH OF SHOE TOP OF CASING WEIGHT OF CASING NEW OR SECONDHAND SEAMLESS OR LAPWELD GRADE OF CASING SIZE OF HOLE DRILLED NO.OF SACKS OF CEM. DEPTH OF CEM. IF THRU PERFS. .20" 618 +67' Schlumberger Jet New Seamless 2611 1200 13 3/8" 2328 +67' blit New Seamless R3 17 1/2" 1100 9 5/8" 4783 +67' 40V New Seamless N80 12 1/4" 500 7" 10,191 67' 23,26 &29 New Seamless N80 8 1/2" 216 PERFORATIONS SIZE OF CASING FROM TO SIZE OF PERFS. NO.OF ROWS DISTANCE BET. CENTERS METHOD OF PERFS. 7" 9140 10,190 1/211 4H IF Schlumberger Jet ELECTRIC LOG DEPTHS_ 290/11,101 &/11,101 & 2901100191 DRILLED BYSantaFe Drj 1 i�� y GRAN?TE POINT PLATFORM FROM NW CORNER OF SECTION 139 T10N, R12W CONDUCTOR "Y" COOR. "X" COOR. Leg#l: 295449566.00 2639297.33 2,544,572.08 263,294.75 2 295449572.41 263,299.33 3 2,544,569.75 263,302.99 4 29,544,565.34 263,303.99 5 2,544,561.34 263,302.08 6 23,5449599.42 263,297.83 7 22544,560.67 263,293.33 8 2,544,564.50 263,290.83 9 2,544,569.00 263,291.42 Leg -,-','2: 29544,610.00 263,364.00 2360 Compressors Legr3: 29544,543.33 263,408.00 12,544,548.16 263,403.42 2 2,544,549.91 263,407.59 3 2,544,548.66 263,412.00 4 29544,544.99 263,414.41 5 29544,540.42 263,413.91 6 2,5445,537.25 263,410.58 7 2,544,537.00 2639406.09 8 215449539.58 263,402.42 9 2,544,544.08 2631,401.42 Leg4'F'4: 2,544,499.58 2632341.33 WELL # FSL 13-13 2382 22-13 2371 44-14 2391 MUC;',`I-2 - 2373 33-14 & RD 2371 31-23 2380 11-24 2366 31-14 & RD 2362 1&2 44-11 & RD 2360 Open 12-24 2363 32-23 & RD',`2 2368 31-13 2382 22-13 2379 MUC#I-1 2391 MUC;',`I-2 - 2386 32-13, 33-13 2390 24-13 & RD 2392 42-23X, 31-23 2380 11-24 2383 11-13 2379 FEL 1267 1262 1258 1256 1258 1261 1269 1269 1370 1375 1379 1381 1379 1376 1371 1368 1375 • t Mobil Oil Corporation WELL COMPLETION REPORT ORIGINAL DRILLING co 152260-06) OPERATOR Mobil Oil Corporation LAND OFFICE LEASE NO. WELL No Granite Point State 31-14 OH, RD/tl) ELEVATIONS 110' (K. B. (MAT) FIELD Granite Point WPZ ENGINEER SEC. 14 T. ION R. 12W S.M. g & H GEOLOGIST J. Meyer & H. Hixson STATE Alaska 9 COUNTY Kenai DATE 11/3/67 9. WELL NO. Form 10-403 Submit "Intentions" In Triplicate RFV. 1-10-73 & "Subsequent Reports" in Duplicate (L E,, ..M_ STATE OF ALASKA 5. API NUMERICAL CODE OIL AND GAS CONSERVATION COMMITTEE 50-133-10061 6. LEASE DESIGNATION AND SERIAL NO. SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT—" for such proposals.) ADL 18761 1. OILGAS [:] 7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAM UNION OIL CO. OF CALIFORNIA UNION - MOBIL STATE 41 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. BOX 6247 ANCHORAGE ALASKA 99502 GPS 31-14 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT At surface GRANITE POINT 2362' S & 1258' E from N.W. corner, Sec. 13, T10N y i 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) R12W, S.M. Leg #1 Conductor #5 Sec. 14, T1DA,__R12W. S.M. 13. ELEVATIONS (Show whether OF, RT, GR, etc.) 12. PERMIT NO. KB 95' above MSL 66-56 14. uneCK Appropriate tiox i o .indicate Nature OT Notice, Keport, or utner Uata NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: TEST WATER SHUT-OFF PULL OR ALTER CASING WATER SHUT-OFF REPAIRING WELL FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING .SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) (Other) —CHANGE OF OPEATOR (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. FROM: MOBIL OIL;. CORP. TO: UNION OIL,CO OF CALIFORNIA V �+D GiviSla►t Al 1�►� � t:�►�� n4;►)�;F+�•vc��i�n A(j(;Ii5jr'� c� Mobil .0 8: Corporation Mr, L. C. Smith State of Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Smith:. POST OFFICE POUCH 7-003 ANCHORAGE, ALASKA 99510 February 22, 1973 The following comments are in reply to e request on your field inspection report dated. February.14, 19 3, and. our telephone conversation on February 21, 1973, con erning notification.of Mobil's plans regardin communication between the 9 5/8" and 13 _ 3/8" casing i Gra�ni etet Point well No. 31-1 .= The pressure buildup on the 9 5/8" and. 13 3/8" casing had been observed. earlier this year. We have determined there is no apparent communication from the 7" casing to the 9 5/8" casing. As you know, this well is produced via gas -lift, and the 7" casing is pressured to approximately 775 psi for this type operation. We feel the pressure buildup in the 9 5/8" and 13 3/8" casing is probably shallow coal gas. A gas sample has been taken for analysis so that we can compare this gas with the produced gas used. for gas - lift. Our intent, at present, is to continue observation of the casing pressure. Possibly later on during a period. when we are performing other well work actively, we may decide to eliminate this communication by cementing or placing heavy mud. in the casing strings. Y urs very truly, L. A. Davis Area Operations Supt. S GAS 7 r„I _. iii 3 _Er 4 ENC9� S ENG 6,EOL -2 GEOL 3 GEOL,- REV DRAFT I SEC I CONFER: fti11fi1/C(iItlt1lt1ff/f1t11!ttfIl!1fi1f1it1{Ifltliti1!1i1111INN 1f1!tt1Mi: 1lff(f//[ti!/!!/lflli(t a, Ill Ill I!(1f(i!1l!f1!11!11!11((/{ff/(t!ti!ifl{tlfs1/1/ifltf1i1f(1■tf/(fatlf1f1tt11/11tf!t/!lt(!ol1fflt1tt1i/1i/11f/!i■11■(u1�(f1/1■H1■1■{1.11.11■![s11■#.(11■11■!1■{1■11ii11tiiti It .! t1lEliiitfll#itiili111t111111t1111111111111111t1111[11111i111i111111111111 111111111111IIIi111i111ti111i1)111/i1/11111111tI11111111if/f11i11/111#llii111g1 Hill H fH IIIIIf1111/#111111111111111111111111lilliiililiiiillllll111llflf IIU/111111i111i11tItt111"all IfUsItoo Iloilo Hill still Ilift MH 11111tilt##/111 itfilltliltitll/IIIifit11111lI1111l111111IIIIfIff11f11111titlltilfllillfll 1111!1111!1111111Illllltilt11111Nlifllliilitll11/IIIIII1111 N1111llllliiiiif111 lull Ill 11Ill 11111111111111111111111111111111111111111111111111!{Iifiillll 11111!!ttlillt11I111iIIiIItItl ltlliilltttliilitltllRttltl!!tl1111llllllltlltttll Iltilllltitll{liltfill{Illtflltllltlitftiitilttif11f111N11►tflflllfll►fif Iflltllittiffit11N11111111111if1l11l1!l1111#1111111tlt11it11t111illlt!lt1i1l1i1 iillfilllliltltlHllflililiflliilllii1111111lilll!li1111111HfiftlftliHli 11111111f1l111f1t11Ii1Itii1111Hlflfliillifl11111l11HIII1111if1l11Nittitttt111 1Ill 111IIIHill 1111111111Hill 111111111111111tfiffill If111111111111111111111i1i111111Hill fill IHill Hill 1111111111ill 1111111fill[ 11i11 Hill 1111111111!111! Mobil Oil Corporation 612 SOUTH FLOWER STREET v NORTHWEST PRODUCING AREA LOS ANGELES, CALIFORNIA 9W54 P. 0. Box 1734 Anchorage, Alaska December 12, 1967 Mr. Harry W. Kugler State of Alaska Division of Mines and Minerals Oil and Gas Section;<_. 3001 Porcupine Drive Anchorage, Alaska Dear Harry: Enclosed are amended copies of Forms P-,7 and P-3 for Well #31-14. The platform location of this well has been corrected to read: 2362' S and 1258' W from the NW Corner of.Section 13, T10N, R12W. Sincer ly, 1 Harry C. Hixson HCH:sjs Enclosures RECEIVED El► D1V)Sl()N OF Mtn+ES ANCHORAGE M�NF�ALS E C% F. E r2 - r C1 ti a 151V1§115N OF M1W_ 41 Form P-7 !`� SUBMIT IN DUPI' • v JATIE OF ALASI(A (y. Y r iii- i;ffcctive: July 1, 1964 struct-ns on OIL AND GAS CONSERVATION COMMISSION reverse side) 5. TEASE DESIGNATION AND SERIAL' NO. State ADL 187 61 s• IF INDIAN, ALLOTTER OR TRIBH NAME /. UNIT ACREEJIENT NAME WELL COMPLETION OR RECOMPLETION DEPORT AND LOG''` Ia. TYPE OF WELL: oIL. GAs._. _..._ WELLIfl WELL DRY D Other b. TYPE OF COMPLETION: 4N NEW WELL D OVER WORK ERK ENEP BACK RESVRPLUG DIFF. . ❑ Other Radrill S. FARM OR LEASE NAME Union -Mobil State #1 2. NAME OF OPERATOR Mobil Oil Corporation 9. WELL N0. Granite Point State #31 -14 Re d r i l l #1-1 3. ADDRESS OF OPERATOR P. 0. Box 1734, Anchorage, Alaska 99501 10. FIELD AND POOL, OR WILDCAT 8 1/2 Granite Point -Middle Kenai 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements) At surface 2390'S & 1449'E from NW Cor. , Sec. 13, :TION, R12W, S .M. jj, sec., T., n., M., Olt IILOCK AND SURVEY i1rS$ Leg #1 Conductor #5 -of' platform OR.AREA At top prod. interval reported below 9025MD, 8580VD, 870'N & 1499'W from Surf Sec. 14, TION, R12W, S .M. location Cook Inlet At total aepth11,011MD, 10,487VD, 923'N & 983'W 'from surface locat. PERMIT NO. DATE ISSUED 12. BOROUGH 13. STATE 114. : 66-56 I Kenai , Alaska 10. DATE SPUDDED Drilled out 1 16. DATE T.D. REACHED17. DATE COMPL. (Ready to prod.) 1 18. ELEVATIONS (DF, RKB, RT, OR, ETC.) * 1105.9' I 19. ELEV. CASINOHEAD 3-18-67 5-28-67 Abnd. 7-20-67 above MLLW (K.B .) 67' 20. TOTOlA1MD DEPTH, MD TVD PLUO, BACK T=D., 22. IF MULTIPLE COMPL., 23. INTERVALS ROTX Y TOOLS CABLE TOOLS 11, 10� 487 ' �1D. 4805MD 4464VD HOW MANY+ 1 DRILLED BY I 24. PRODUCING INTERVAL(S), OF THIS COMPLETION -TOP, BOTTOM, NAME (MD -AND TVD)* 25. WAS DIRECTIONAL Middle Kenai - Producing Interval SURVEY MADE I Top - 9025MD, 8580VD, 870'N & 1499'W from surface location Bottom = 10,884MD, 10,378VD, 935'N & 1048'W from surface location es I y 26. TYPE ELECTRIC AND OTHER LOGS RUN 27. WAS WELL CORED IES; Sonic, Dipmeter, Dual Induction, Proximity`t.og & Dual Caliper .) No 29. CASING RECORD (Report all strings set in !Dell) CASINO SIZE WEIGHT, LB./ST. DEPTH SET (MD) HOLE SIZE CEMENTING RECORD AMOUNT PULLED 9 5/8" 4N 4783 12 1/4 500 sax Class "G" 7 23,26 & 29# 9548 8 1/2 900 Sax Class "G" 29. LINER RECORD 30. TUBING RECORD SIZE TOP (MD) BOTTOM (AID) SACKS CEMENT* SCREEN (MD) SIZE DEPTH SET (AID) PACKER SET (MD) 511 9489 10,999 300 82. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 33.' PRODUCTION DATE FIRST PRODUCTION PRODUCTION METHOD (Flowing, gas lift, pumping -size and type of pump) WBLI. STATUS (Producing or 1 1 Shut-in) ` Abnd. DATA OF TEST 1 HOURS TESTED 1 CHOKE SIZE 1 ODN. FOR OIL-BSL. GAS-AICF. NATER -BBL. GAS -OIL RATIO TR I I � FLOW, TUBING PRESS. CASING PRESSURE CALCULATED OIL -BBL. GAS -MCF.., WATER -88L. OIL GRAVITY -API (CORR.) 1 1 24-HOUR RATE 34. DISPOSITION OF GAS (Sold, used for fuel,, vented, etc.) TEST WITNESSED BY I LIST OF ATTACHMENTS Diagram of Fish left" iii; Hole I hereby certify that the foregoing and attach c SIGNED *(See TITLE i complete and Correct as deters Area Engineer ns and Spaces For Additional Data on Reverse Side) _ ., avaname DATI,� I/O/F71 V ( / r NOU R 2 1957 DIVIS IONV Of MINES & MINE &•, AW-HORAGE y rr Form P-7 SUBMIT IN DUPLIEffective: July 1, 1964 'STATE OF ALASKA tsela of r in= structions on -- O:L AND GAS CONSERVATION COMMILSION reverse side) 5. LEAS., DESIGNATION AND SERIAL' NO. State ADL 18761 WELL C0MPL.'_TiON OR RECOMPLETION REPO!---,T AND LOG * s. IF I DIA , ALLOTTEE OR TRIBE NAME 1a. TYPE OF .011, GAS. 7. UNIT ACItEWNIENT NAME WELL WELL DRY Other — b. TYPE OF COMPLE ON: i DEEP- PLUG DIF F. `.•.:".L. '_% OVFi. tJ EN I� BACK � RESVR. El Other '� S. I�.1It:i �itc LEASE NAME Woni 2. -.:Aft. or of%.RATGR Union—Mobil State #1 Mo:)i Gil Corporation 9. WELL; 'soGranite Point SE'ate S: Aii -iti".Ss ..b' u.'FRATOR #31-,4 OH & Sidetrack 0. Box 1734, Anchorage, Alaska 99501 110 rIA LD POOL, OR WILDCAT LOCATION OF WELL (rivi).rt Clearly and in accordance toith wiStat: reQ• n "'au;:ts)• i; 1 ..i. I lint — Middle Kenai Ateurface 239011S & 133 'E from NW Cor. Sec. X13, TION, R12W, S.M. -:---- ( L� M., 0,t BLOCK AND SURVEY Leg #1, Conductor #5 of platform At top pro,: i%terval re:�orted beioR TIGN, R12W, S .M. Middle Kenai prod, interval not penetrat. S�;c- At 0H=E,1il0 M.D. , 8187 V.D. , 1508'N & 2589'W frgm sErf. Cook 1-,-il��t sidetrack = -876 M.D. 8257 V.D. 14. PERMIT NO. DATE ISSO Da ion 12. 1,c: STATIM 'N & 2600'W from sur ace location I 66-56 Kenai Alaska 1.i. DATE SPUDDED 16. DATE T.D. REACHED 17. DATE COMPL. (Ready to prod.) 18. ELEVATIONS (DF, RKB, RT, OR, ETC.) • Ifl. F.t.... ASINGHDAD 12-24-66 1 3-4-67 I 1105.9'.above MLLW (K.B.)! 87' 21. PLUG, BACI{ T.D., MD & TVD 22. IF MULTIPLE COMPL., 23. INTE-C ALS ROTARY TOOLS CABLE TOOLS HOW AfANY* DRILLED BY _7VDI 4863MD = 4526VD 1 X _ 24. PRODUCING INTERVAL(8), OF THIS COMPLETION—TOP, BOTTOM, NAME (MI) AND TVD)' ( 25. AS DIRECTIONAL .URVi;Y MADD yes 26. TYPE ELECTRIC AND OTHER LOGS RUN 1 07. WAS WELL CORED I.E.S., Sonic, Dipmeter and C.B.L. No 23. CASING RECORD (Report all strings act in well) CASING SIZE WEIGHT, LB./FT. DEPTH SET (AID) HOLE SIZE CEJLF'.\'TING R:�.'JRit _ I AMOUNT PULLED 20" 618 26" 1200 sax C s a_.,, ''k"- 13 'k":1361# 2328 17 1/2" 800 sax s.. 3 Si/Ii b 11 4CO 4783 12 1/4 500 sax C1as-: - CIn.' 29. LINER RECORD 30. TUBING RECOi:1:) �.:,. TOP (MD) BOTTOM (MD) `SACK$ CDMENT° I SCREEN (MD) SIZE DEPTH SET (M—)) � ICER SET (MD) 31. P&AIFORATION RECORD (Interval, size an 82. ACID, SHOT, FRACTURE, CEM–' N .' SQULl::: ', V:TC. DEPTH INTERVAL (MD) AMOUNT AND r:iNu OF h[A: <:..': USED 33.• PRODUCTION DATE FIRST PRODUCTION PRODUCTION METHOD (.Flowing, gas lift, pumping—size and type of pump) WELL STATUS (Producing or shut-in) Abnd. DATE OF TEST HOURS TESTED CHOKE SIZE FROWN. FOR OIL—BBL. GAS—MCF. `,Bi.. GAS -OIL RATIO 1 1 1 TEST PERIOD FLOW. TUBING PRESS. CASING PRESSURE CALCULATED OIL—BBL. GAS—MCF. WATER—BBL. 011, GRAVITY.—'! (CORA.) 1 124 -HOUR RATE I 34. DISPOSITION OF OAS (Sold, used for fuel, vented, etc.) TEST Wi'i N eSSED BY 3;r. LIST OF ATTACHMENTS 4: 38. I hereby certify that the .ore Ding and attach d information is complete and correct as determined from all availa,o..• : ueords — �+� Area Engineer �` 1//�7 V E D Sri tiED TITLE *(See Instructions and Spaces for Additional Data on Reverse Side) DIVISION OF MINES 8[ MINERALS R ANCHORAGE " D INSTRUCTIONS Gentral: This form is designed for submitting a complete and correct well cou�pietion report and log on all types of lands and leases to either a Federal agency or a State agency, or both, pursuant to applicable Federal and/or State laws and regulations. Any'necessary special instructions concerning the use of this form and the number of copies to be submitted, particularly with retard to local, area, or regional procedures and practices, either are Shown below or will be issued by, or may be obtained from, the local Federal and/or State office. See illst.ruct-ions on items 22 and 21, rand 33, belowregarding separate reports for separate completions. If not filed prior to the time this summary record is submitted, copies of all currently available logs (drillers, geologists, sample and core analysis, all types electric, etc.), forma- tion and pressure tests, and directional surveys, should be nttached hereto, to the extent. required by applicable Federal and/or State laws and regulations. All attachments . should be listed On this form, see item 35 - Item 4: If there are no applicable State requirements, locations on Federal or Indian land should be described in accordance with Federal requirements. Consult local State . or Federal office for specific instructions. Item 18: Indicate which elevation is used as reference (;'here not otherwifsn shown) for depth measurements given in other spaces on this form and in any attachments. Items 22 and 24: If this well is completed for separate production from more than one interval zone (mul:.iple Completion), So State in item 22, and in item 2-31 Show the producin;; interval, or intervals, top(s), bottoin(s) and nalne(s) (ii £an;;) for 0111Y the interval rel oz -1 ad in iten1 acv. Submit a separate report. page) oil tliis forth, adequately Idelitified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. - Itera 29: "Sacks Cement": Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementinb tool. Item 33: Submit a separate completion report on this form for each interval to be separately produced. (Sea instruction for items 22 and 24 above.) 37: SUMMAI{Y OF POROUS ZONES SIIOW ALI, IMPORTANT ZONES OF POROSITY AND CONTENTS THAI:T.0r; CORED INTL'RVALS; AND ALI. DRILL -STEM TESTS, INCLUDING 36. GEOLOGIC MARKERS a: I" DEPTH INTERVAL TESTED, CUSHION USED, TIME TOOL OPEN, PLOWING AND SIIUT-II4 PRESSURES, AND RECOVERIES FORMATION TOP" BOTTOM DESCRIPTION, CONTENTS, ETC. TOP NAMD ]!LEAS. DEPTiI TRUE VERT. DEPTH PAP Middle Kenai 8580 VD 10,378VD Sandstone &Conglomerate "- oil saturated Three Fringes Coal 6800 6377 a" Z z: _ 0. rn _.odd :,� Form P-7 SUBMIT IN DUPi j STATE OF ALASKA (Serot,,l,jrin= struct'Cas on OIL AND GAS CONSERVATION COMMISSION! reverse side) WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. TYPE OF WELL: OIL Gas WELL ® WELL F DRY ElOther b. TYPE OF COMPLETION: NEW WORK DEEP- PLUG DIFF. Redrill WELL � OVER � EN � BACK D RESVR. El Other 2. NAME OF OPERATOR Mobil Oil Corporation 3. ADDRESS OF OPERATOR P.` 0. Box 1734; Anchorage, Alaska 99501 4. LOCATION OF WELL (Report location clearly and in accordance with any ,State requirements)" At surface 2-3-90"S & 1-3,7-9'E from NW Cor. Sec. 13, TION, R12W, S .M. 17-x8 t . Leg #1 Conductor #5 of platform At top prod. interval reported below 914OMD, 8673VD, 910'N & 589'W from surface location At total depth 10 , 9' MD , 97 GOVD, 871'N & 1374'W from surf . loc-at ion Effective: July 1, 1964 5. LEASE DESIGNATION AND SERIAL' NO. State ADL 18761 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME S. FARM OR LEASE NAME Union -Mobil State #1. 9. WELL NO•(iranite Point State #al -14 Redrill #2 10. FIELD AND POOL, OR WILDCAT' Granite Point -Middle Kenai 11. SEC., T., R., 11., OR BLOCK AND SURVEY OR.AREA Sec. 14, TION, R12W, S.M. Cook Inlet t 14. PERMIT NO. DATE ISSUED 12. BOROUGH 66-56 I Kenai 5. D S UDI)l 16 DATE T.D. REACHED 17. DATE COMPL. (Ready to prod:) 18. ELEVATIONS (DF, RED, RT, OR, ETC.) • 7-21-67 8-24-67 9-7-67 1105.9' above MLLW (K.B.) 20. TOTAL DEPTH, MD & TVD 21. PLUG, BACK T.D., MD & TVD 22. IF MULTIPLE COMPL., . 23. INTERVALS ROTARY TOOL: HOW MANY* DRILLED BY 10 191MD=97OOVDI -0 X 24.' PRODUCING INTERVAL(S), OF THIS CONIPL.ETION-TOP, BOTTOM, NAME (MD AND TVD)*. Middle Kenai producing interval To = 914OMD 8673VD ' Bo tom = 10,19lMn 970OVD 26. TYPE ELECTRIC AND OTHER LOGS RUN ' 23_ CASING RECORD (Report all strinos set in well) 13. STATE Alaska D. ELEV. CASINOHEAD 671 CABLE TOOLS 25. WAS DIRECTIONAL SURVEY MADE WAS WELL CORED CASINO SIZE WEIGHT, LB./rT. DEPTH SET (MD) HOLE SIZE CEMENTING RECORD AMOUNT PULLED 711 23,26 & 29# 10,191 8 1/2" 216 sax class "G" 101042- 10,152 = 110 9445 - 9600 = 155 10,180- 10,190 = 10 9680 - 9725 = 45 33. • PRODUCTION DATE FIRST PRODUCTION PRODUCTION METHOD (Flowing, gas lift, pumping -size and type of pump) WELL STATUS (Producing or 29. LINER RECORD 30. TUBING RECORD SIZE TOP (MD) BOfiTOM (MD) SACKS CEMENT* SCREEN (MD) SIZE DEPTH SET (MD) PACKER SET (MD) GAS -OIL RATIO 24 124/64 3 1/2 OD 9716 9067 -9-1,-67 FLOW. TUBING PRESS.CASING PRESSURE CALCULATED OIL -BBL. GAS -MCF. WATER -BBL. OIL GRAVITY -API (CORA.) 27 2 I 7 4 Ilt24-Hou 31. FNRFURATIUN UNVUBD timervai, size ana numver, 4H/ft. 1/2" Holes 32. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9140 - 60 = 20 9980 - 10,025 = 45 9165 - 85 = 20 101042- 10,152 = 110 9445 - 9600 = 155 10,180- 10,190 = 10 9680 - 9725 = 45 33. • PRODUCTION DATE FIRST PRODUCTION PRODUCTION METHOD (Flowing, gas lift, pumping -size and type of pump) WELL STATUS (Producing or shut-in) 9-9-67 Flowing Producing DATE OF TEST HOURS TESTED CHOKE SIZE PROWN. FOR OIL -BBL. OAS-DICF. WATER -BBL. GAS -OIL RATIO 24 124/64 TEST PERIOD ---3• I 3083 1646 5 533 -9-1,-67 FLOW. TUBING PRESS.CASING PRESSURE CALCULATED OIL -BBL. GAS -MCF. WATER -BBL. OIL GRAVITY -API (CORA.) 27 2 I 7 4 Ilt24-Hou ,R> I 3 083 I 1646 I 5. I 41.0 34. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) TEST WITNESSED BY vented 35. LIST OF ATTACHMENTS History,Diagram of Completion Equipm ent, Directional Surveys, W.S.O. Test Records 36. I hereby cert y at the f regoin� and attach d information is complete and correct as determined from all available records �� Area Engineer I v E D SIGNED TITLE ff DATE'RlF/C/F *(See Instruct ons and Spaces For Additional Data on Reverse Side) N n V 22 197 I)IVISIUN Of MINtb &•"MINERAL, AK rN14arE. eticin t and ses to er a al agency or a General: This form is designed for submitting a eamplcte IZInI correct re 11 I1 oust cAnylllecc slryispecialo nstructions conecruln- t elelt e of this sform rand rthe number ofScopies�to be or both, pursuant to applicable I ederal and/or State laws II d _ �d Iart.icularly with regard to local, area, or regional procedures and practices, ��Tate re )orts for Separate Completions. issllecl by, or may be obt<zined frou�, the local �'edeial. " submitted, l and/or St ate office. See iI1Str11Cti011S on 1tCIlIs `�� and 24, and , copies below > all cur e s I l core Ii not filed prior to the tillle thissulumary record is subulit;t�Lched heretoctolthelextent y. •Iequired b�yrapplicable oFederal and/or State lawsandregulations.l types C, All attaclime is _ tion and pressure tests, and directional surveys,should be ta should be listed on this form, see item 35... _giloj 4: If sed are no applicable State requirements, locations on Federal or Indian land shottld be described in accordance with Federal requirements. Consult local tate or 1'edcr.al otlice for specific instructions.uts given in ii •at.� which elevation is used as reference (where not othe=wise Shown) for de l zone n i ltiele completion), sostate in item 122, and ins forin a elnin a24 show theachmproducing iirelrl i 3ny att : Indicate hems 22 and 24: If this ivell is completed for separate production from more than one interval P a e on this form, adequately identified, interval, or intervals, top(s), bottoms) and nalne(s) (if any) for only the interval reported in item 33: Submit a. separate report (p €; ) for eacl, oadditional i er interval to he separately produced, showing the additional data pertinent to such interval. and the location of • a. hs Ceuler:.t": Attached supplemental records for this well should show. the details of oduceyciulSCeeinstructionefor teles 22 and 24 above.) Cementing cool. Itep-r 29.., 5 c {tcln.3:;: Submit a separate completion report on this.form for each interval to be separate y p 37. SUM, Qb' POROUS ZONES: �+ GEOLOGIC DiARIi:�;RS SIIOLY ALI. I�IPORTAST ZONES OF POROSITY AND CO=NTENTS TIIF,REOF • CORED INTERVALS ; AAD ALL DRILL 3TE,1f TESTS, INCLUDING Sag• ' DEPTH INTERYA,L TESTED, CUSIIIO:I USED, TIME TOOL OPEN,- FLOWING AND SHUT -f II Pl'-:.,,SURES, AND RECOVERIES TOP TOP ROTTO•li DESCRIPTION, CONTENTS, ETC. NAMD FOR.IIATION TIERS. DEPTH TRUEVERT.DEPTH -- Middle Kenai 8673 0 970OVD Sandstone. & Conglomerate - oil saturated WSO ��1 9945MD 1 hr 10 min. test. No fluid recovery salt water cushion - 76#/cu.ft. WSO ��2 9782ND 2 hr. test. Recovered 3500' rise of emulsion and fresh water salt water cushion - 76# /cu. ft, IFP = 45 psi. FFP = 312 psi FSIPr= 1.935 psi WSO #3 908514D 1 hr test. Recovered 2 bbl gas cut mud & 0.7bbl mud & water IFP = 116 FFP= 218 OPERATOR WELL NO. -DATE Date 1966-67 2/24-12/25 2/25-12/26 12/27 2/28-12/31 , MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL Mobil Oil Corporation Granite Point State #31-14 November 11, 1967 DRILLING A MIDDLE KENAI ZONE WELL FIELD Granite Point Sec. 14 T ION R 12W S.M. Signed C. C. Woodruff Title 'Area Engineer This well was drilled•by Santa Fe Drilling Company using rotary rig #72 positioned over conductor #5, leg #1 of Mobil 0il Corporation's Granite . Point Platform. All depths refer to the Kelly bushing 105' above mean low low tide. Drilling 12 1/4" Hole to 365' A 12 1/4" hole was spudded at 7:00 PM, 12-24-1966. Opening 12 1/4" Hole to 17 1/2" 260'/365', Drilling 17 1/2" Hole 365'/667_', Running Schlumberger Logs. Opened 12 1/4" hole to 17 1/2" 260'/365' and drilled 17 1/2" hole to 667'. s } Conditioned the hole and ran the following Schlumberger wireline services: I.E.S. log 290'/667'. Opening 17 1/2" Hole to 26" 292'/625', Recovering Junk in Hole Opened 17 1/2" hole -to 26" 292'/625', leaving two cutters and two pins in hole. IMade two runs with a 9" Magnet, .re c overing 1 pin and small pieces ��of iron. Ran a 12 1/4�� bit and drilled 667 /672 . Opened the 12 1/4 hole 667'/670'. Ran in. with a 12" Bowen junk basket and recovered 2 cones, 1 pin and.pieces of iron. Ran a 22" feeler to 624' and conditioned the hole for casing. Running and Cementing 20" Casing, Installing B.O.E. and Prepairing Hole to -Drill Ahead. 618' of 20" casing was run with top of bottom details as follows: 15 joints- 618.04' of seamless slip joitnt casing with Baker guide shoe. The casing wasandd at 618' K.B. and cemented with 1200 sax Class G neat cement mixed with seawater.4 Approximately 100 cu.ft. of cement was returned to surface. Installed riser assembly and B.O.E. Ran in with 17 1/2" bit and found top of cement at 545'. Tested B.O.E. and casing with 825 psi., tested O.K. Drilled hard cement 545'/619' and cleaned out to 672'. - 1 - MOBIL 'OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR Mobil Oil Corporation FIELD WELL NO. Granite Point State #31-14 Date 1967 1/1-1/5 1/6-1/7 1/8 DATE November 1, 1967 Granite Point Sec. 14- T ION R" 12W S.Ma S iIr gned C. C. Woodruff Title Area Engineer Drilling 12 1/4" Hole 672'/2560', Running Schlumberger Logs. Ran in with a 12 1/4" bit on a 6.1/2" Dynadrill using a 2 degree kick sub. Drilled with Dynadrill 672'/1582.'. Drilled 12 1/4" hole 1582'/2560' with a regular set up including a 121/4" Drilco reamer. Five hours were lost thawing water and mud lines. The following Schlumberger wireline services were run: I.E.S. log 613'/2538', sonic log 613'/2510', and -CDM log 613'/2516'. Opening 12 1/4" Hole to 17 1/2" 618'/2350'. Opened 12 1/4" hole to 17 1/2" 618'/2350', and conditioned hole for casing. Running and Cementing 13 3/8" Casing. 2328'of 13 3/8" casing. was run with the following bottom to top details: 59 joints - 2328' - 611f R3, ST&C 8 rd. thd. with a Baker flexiflow shoe on bottom and flexiflow collar 2 joints above .bottom. This casing was landed on an L.T.C. head 43' below K.B. The shoe was cemented at 2328' with 800 sax class G cement with 3% prehydrated gel, followed by 300 sax neat cement mixed with 2% calcium chloride. The 95# to 115# slurry was.dis- placed at a maximum pressure of 750 psi. with good returns to the surface. 1/9-1/11 ' Squeezing Cement in Annulus between 20" and 13 3/8" Casing; Installing B.O.-E. Tore out 20" B.O.E. and riser assembly. The well started to kick out cement from between 13 3/8" and 20" casing.' A 3/4" pipe was run 180' into the annulus and gas cut cement was circulated out. 350 sax of class G 115# cement slurry was pumped intq;;te annulus without stopping the gas. The 20" riser assembly and B.O.E. was reinstalled and an additional 600 sax was squeezed at (V pressure. This was followed by 200 sax in 20 sack stages using a maximum pressure of 600 psi. Gas continued to escape through the annulus. Squeezed additional cement with 1500 psi. maintaining the pressure for"6 hours. Installed 13 3/8" riser'and B.O.E. and checked for gas leak. Checked O.K. - 2 OPERATOR WELL NO. Date 1967 1/12-1/13-- 1/14-1/31 2/1-2/12 MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL Mobil Oil Corporation Granite Point State #31-14 DATE November 1, 1967 FIELD Granite Point Sec. 14 T ION R 12W S.M. Signed C. C. Woodruff Title Area Engineer Cleaning Out Cement, Running Schlumberger Cement Bond Log and Sperry -Sun Multi Shot Survey.* Ran in with 12 1/4" bit and found cement at 1905'.. Drilled hard cement 1909/2308'. Ran a Schlumberger CBL 100/2291 and a Sperry -Sun multi shot survey. Prepaired to test B.O.E. and casing. Testing B.O.E., Drilling 12 1/4" Hole 2560'/7278', Running Schlumberger Logs. Tested B.O.E. and riser assembly with 3500 psi., O.K. Tested the 13 3/8' casing with 1200 psi., O.K. Ran in with a 12 1/4" bit on a regular set up and drilled out cement 2308'/2328'. Drilled out shoe at 2328' and continued to make new 12 1/4" hole 2560'/6016'. Ran in with a 12 1/4" bit on a 6" Dynadrill using a 2 degree kick sub. Drilled 12 1/4" hole 6016'/6350'. Drilled 12 1/4" hole with a regular set up 6350'/7278'. Ran the following Schlumber wireline services: I. E. S. log 2324'-7270, CDM log 2324' - 7262' and sonic log 2324' - 7258'. Drilling 12 1/4" Hole 7278'/8280', Drilling on Junk 7486'/7492', Running Schlumberger Logs. Ran in with a 12 1/4" bit.on a 6 1/2" Dynadrill with a 2 degree kick sub, and drilled 12 1/4" hole 7278'/7307'. Ran in with a 12 1/4" bit on a regular set up and drilled 7307'/7455'. Ran in with a 7 3/4" Dynadrill and drilled 12 1/4" hole 7455'/7486'. Pulled out and left three cones in hole. Ran in with a 12" Bowen reverse circulating junk basket and drilled on junk 7486'/7487' with no recovery. Ran a 12 1/4" bit with a junk sub and drilled on junk 7486'/7492' with no recovery. Continued drilling 12 1/4" hole with the above set up. 7492'/7635'. Drilled 12 .1/4" hole with a regular set up 7635'/7917'. Ran a 12 1/4" bit on a 7 3/4" Dynadrill with a 2 degree kick sub And drilled 7917'/7940'. Drilled 12 1/4" hole with a regular set up=,940'/8043'. Ran Dynadrill and drilled 12 1/4" hole 8043/8082'. Drilled 12 1/4,.,h,6)e with a regular set up 8082'/8280'. Repaired hole to run logs... Ran the following "Schlumberger wireline services: I.E.S..log 2326'/8254', CsD.M. 7200'/8248' and sonic 7000'/82571. 3 - i ti MOBIL OIL CORPORATION v . HISTORY OF OIL OR GAS WELL OPERATOR Mobil Oil Corporation FIELD Granite Point WELL NO. Granite Point State 131-14• Sec. 14 T ION R 12W• S.M. Signed C. C.. Woodruff DATE November 1, 1967 Title Area' Engineer Date 1967 2/13-2/14 • Drilling 12 1/4" Hole 8280'/8352', Freeing Stuck Pipe._ Drilled 12 1/4" hole with a regular set up 8280'/8352'. Stuck pipe on.bottom while making a connection. Spotted 25 bbl. diesel mixed with 1 bbl. Freepipe. Loosened and recovered drill pipe.. 2/15-2/17 Drilling 12 1/4" Hole 8352/8810 - Total Depth Original Hole. Drilled 12 1/4" hole with a regular set up 8352'/8810' total depth. 2/18-2/22 Fishing for Stuck Pipe, Plugging Back to Sidetrack Original Hole. Stuck pipe on bottom while circulating. Mixed 50 bbl. diesel and 2 bbl. Freepipe, pumped 40 bbl. down drill pipe and 20 bbl. into annulus. Could not circulate with 1 3000 psi. Ran Dialog freepoint, pipe free at 8560'. Backed off at 8557. Ran in hole with 12 1/4" bit, reamed and washed 8225'/8556'. Ran in with washover pipe. J Could not get over fish, wash pipe stuck while breaking off Kelly. Jarred loose leaving washover shoe and one joint 10 3/4' wash pipe in hole. Ran in with 12.1/4" i 'bit and reamed tight.spots 2667'/6410'/7340'/7699'. Located top of fish-at 8502'. Pushed wash pipe down to 8517'. Ran open end 5" drill pipe to 8516' and pumped'' in 150 sax class G cement plus 10% sand. 2/23-3/3 Drilling 12 1/4" Hole 8350'/8876' - Total Depth Sidetrack of Original Hole. Cleaned out soft cement 8325'/8345' and drilled hard cement to 8350'. Ran in with 12 1/4" bit on 7 3/4" Dynadrill assembly and drilled 12 1/4'-'--- hole l drilled 12 1/4" hole 8350'/8369. Pulled out of tight.hole and ran in with a 12 1/4" bit on a regular drilling assembly and drilled 8369/8765. Had tight hole conditions and stuck pipe at 8762'. Continued drilling 8745'/8876' total depth. ,/4-3/10 Fishing Stuck Pipe�Running Schlumberger Logs. Stuck pipe while rotating at 8809'. Spotted 50 bbl.. diesel and 2 bbl. Freepipe k loosening the pipe. Drill pipe parted during trip, leaving drilling assembly and 20' of 5" drill pipe in'hole, top of fish 8348.', bottom 8804'. Ran in with a k 9 3/8" Bowen overshot- could not get over fish. Ran in with a bent single above the Bowen overshot, could not-get-over fish. Ran in with a 10 3/4 O.D. wall hook f and 9 5/8 Bowen overshot, could not get over fish. Stuck pipe at 3107' while r MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR Mobil Oil Corporation WELL NO. Granite Point State #31-14 Date 1967 3/11-3/12 DATE November 1, 1967 FIELD Granite Point: See. 14 rn•* 12W S.M. S igned _..._.__ Ff Title Area Engineer while pulling out of hole. Ran Dialog string shot and backed off 5" dril pipe at 3044'. Ran in with bumper sub and jars, screwed into fish, and drove down for 3 hours with no results. Pumped in 50 bbl. diesel and 2 bbl. Freepipe with no results.. Ran Dialog string shot and backed off drill pipe at 3075'. Ran 15' joint of drill pipe, bumper sub and jars, and jarred on fish with no results. Spotted 50 bbl, oil and 2 bbl. Freepipe with no results. Ran Dialog, string shot and backed off drill pipe at 30,75'. Ran 15' joint of drill pipe, bumper sub and jars, anal jarred on fish with no results. Spotted 50 bbl. oil and 2 bbl. Freepipe with no results. Down 10 hours due to mechanical and electrical troubles. Continued jarring on fish with no results. Ran Dialog string shot and backed off drill pipe at 307,5'. Ran a 10 3/4" washover shoe and 75' of 7 5/8" washover pipe, could not get over fish. Ran Dialog collar. locator, showed wash pipe alongside fish. Pulled out with wash pipe assembly. Ran an open end drill pipe and screwed in at 3075'. Ran Dialog string shot and backed off at 3044'. Ran in with 10.3/4 0. D, washover shoe on 117' of 9 5/8" wash pipe,,___with bumper sub and jars. Washed over and screwed into fish. Jarred fish loose and pulled out, leaving 5' of 10 3/4" wall hook in hole. Ran ink and reamed tight hole 3029'/3149' and tight.spots5200'/8051'. Ran the following Schlumberger wireline services: I.E.S. log 2327'/8059'. Plugging Back for Redrill #1 Ran open end drill pipe to 5005'. Set plug #1 5005'/4700' with 250 cu.ft. class G cement plus 10% sand displaced with 470 cu.ft. mud W.O.C. 14 hours. Ran in to 5000', no cement.,. Ran in with open end drill pipe to 5005' and set plug #2, 5005'/4700', with 250 cu.ft. class G cement with 10% sand and 2% CaC12. W.O.C. 14 hours. Ran in -and found soft cement at 4714'. Cleaned out to 48001. 3/13-3/18 Running and Cementing 9 5/8" Casing. - 4785' of 9 5/8" casing was run'with the details from bottom to top as follows: 112 joints ,4785.,21' 401f N80 LT&C with Baker differential fill guide shoe on first joint,Baker differential fill up collar on top of second joint, centralizers and Baker .thread lock on the first four joints. - 5 - �- OPERATOR WELL NO. Date 1967 3/18-4/7 4/7-4/8 4/8-4/17 MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL Mobil Oil Corporation Granite Point State #31-14 DATE November 1, 1967 FIELD Granite Point Sec. 14 T ION R 12W S.M. Signed C. C. Woodruff Title Area Engineer The casing was landed at 4782.71 R.T. with the float collar at 4691'. 300 bbl. of light mud mixed with 0.25# /bbl. of paraformaldehyde and 1.5#/bbl. sodium chromate was pumped, followed by 500 sax class G cement mixed with 0.75% TIC. Installed 9 5/8 OCT packing and tested with 1500 psi. Tested B.O.E. and riser with 5000 psi. for 15 minutes, tested O.K. W.O.C. 24 hours. Ran in with 8 1/2" bit and found cement plug at 4690'. -Drilled out float collar at 4691' and cleaned out soft cement to 4778'. W.O.C. Pressure tested casing with 900 psi. had communication. Found leak in O.C.T. package assembly. Attempted to seal with plastic, unsuccessful. Pulled out and removed B.O.E. Retrieved repaired, and installed new O.C.T. assembly. Re- installed B.O.E. and tested casing with 5000 psi., tested O.K. Ran in with 8 1/2" bit and drilled out cement and shoe to 4785', finding no cement below shoe. Set a Baker full bore packer at 4498' and circulated through c annulus between 9 5/8" and 13 3/8" casing. f Pumped 250 sax class G cement with 2% CaC12 through Baker full bore set at 4498'. Squeezed 175 sax around shoe and between 9 5/8" and 13 3/8" casing. Held squeeze. 1 pressure of 1500 psi for one hour. (Drilling 8 1_/2" Hole 4863'/8525' - Redrill #1 lCleaned out cement 4637' to�4863,'. Ran in with a d adrill set u and drilled 8 1/2" hole 4863' to 49681. �_-.___ yn P Drilled 8 1/2" hole with regular set up 4968', to 8392'. Drilled 8 1/2" hole with a dynadrill 839.2' to;8416'. :Drilled 8 1/2" hole with regular set up 8416' to 8525'. f Running Schlumberger Logs. l Ran the following Schlumberger wireline services: I. E. S. log 4783'/8515', isonic log 4781':;,185,09', and Dual Caliper -log 4781'/8509'. 8 1/1 Holea8525'/9445' ,Drilling Drilled 8 1/2 hole with a regular set up 8525'/9445'. .f 1 - 6 - MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR Mobil Oil Corporation WELL NO. Granite Point State #31-14 Date 1967 4/17-4/18 4/18-4/23 4/23-4/25 4/25-4/28 DATE November 1, 1967 Running Schlumberger Logs. s FIELD Granite Point Sec. 14 T ION R 12W S.M. Signed C. C. Woodruff Title Area Engineer Ran the following Schlumberger wireline services: I.E.S. log 8310'/9416',.dual caliper log, tool malfunctioned Drilling 8 1/2" Hole 9445'/9561'; Working Stuck Pipe. Drilled 8 1/2" hole with a regular set up 9445'/9561'. Stuck pipe while circulating on bottom. Spotted diesel and worked pipe. Ran Dialog free point pipe free at 9283'. Backed off at 9283' leaving 278' of tools in hole. Ran in hole with washover assembly and washed to 9398'. Ran free point indicator, pipe 10% free at9375'. Ran back off shot and backed off at 9440', recovering -part of fish. Ran in with washover assembly and washed to 9558'. Screwed into fish and recovered same. Cleaned out hole 9500' to 9561' and conditioned for logs. Running Schlumberger Logs. Ran the following Schlumberger wireline services:- I.E.S. log 8200'/9561', sonic log 4782'/9534', dipmeter 4782'/9534,., Proximity log 7800-9555, Density log 8700- 9558, and Dual Induction log 7800,-9556.. Running and Cementing 7" Casing. 9574'. of 7" casing was run with the details from bottom to top as follows: 36 its. - 1459.22' - 29# N80 Seallock w/Baker differential guide shoe and collar with Baker contralizers on 1st 6 its. and 1st 6 its. treated with Bakerlok''. 57 its - 2351.971' 26# N-80 Seallock 61 its - 2550.39' - 23# N-80 Seallock l.it - 40.98 - 23# N-80 Crossover 73 its - 3043.79' - 23# N-80 8RD LT&C 1 jt;; - 40.41' - 29# P-110 8 RD LT&C 2 jts 83.93'. - 23# N-80 8RD LT&C The casing was landed at 9548' with the Baker differential fill up collar at 9462'. Pumped 50 cu.ft. of water followed by 900 sax class G cement mixed with fresh water. f , _ 7 MOBIL 'OIL CORPORATION HISTORY OF OIL OR GAS -WELL OPERATOR Mobil Oil Corporation WELL NO. Granite Point State #31-14 Date 1967 4/28-5/20 5/20 5/20-5/25 5/25-5/28 5/28 DATE November 1, 1967 FIELD Granite Point Sec. 14 T ION R 12W S.M. Signed C. C. Woodruff Title Area Engineer Installed and tested B.O.P and riser assembly with 5000 psi., O.K. Tested casing with 2600 psi., O.K. Running Sperry -Sun Survey, Drilling 6" Hole. Drilled out float collar at 9462'iand hard cement to 9536'. Ran Sperry -Sun gyroscopic survey 2300/9464. Drilled out shoe at 9549' and cleaned out to 9561'. Drilled 6" hole with a regular set up 9561/9721. Changed to a Christensen 5 15/.16 damond bit and drilled 9721/9818. 'Changed assembly back to a rock bit and drilled 6" hole 9818/10,027. Ran 5 15/16 diamond bit and drilled 10,027/10,208. Ran a 6" rock bit and drilled 10,208/10,556. Conditioned hole to run electric logs. Running Schlumberger Logs. Ran the following Schlumberger wireline services: I.E.S. log 9561/10,548. Drilling 6" Hole 10,556'/10,780', Fishing Stuck Pipe. Drilled a 6" hole with a regular assembly 10,556/10,780. Stuck pipe at 10,730' while running in hole. Twisted off at Kelby sub. Spotted diesel and Freepipe. Ran Dialog free point indicator and back off shot, found free at 10,540'. Backed off at 10,515'. Screwed into fish at 10,575', jarred down and freed fish. Pulled and recovered same. Drilling 6" Hole 1.0,780/11,011. Ran in with regular drilling assembly and drilled 6" hole 10,780/11,011. Conditioned hole to run electric logs. Running Schlumlierjer Logs. Ran the following Schlumberger wireline services: I.E.S. log 9557-10,996 and sonic log 9555-10,980,- Conditioned 555-10,980: Conditioned hole to run 5" liner. - 8 - 1r, MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR Mobil Oil Corporation WELL NO. Granite Point State #31-14 FIELD Granite Point Sec. 14 T ION R 12W S.M. Signed C. C. Woodruff DATE November 1, 1967 Title Area Engineer Date 1967 5/28-5/30 Running and Cementing 5" Liner. 1511' of 5" liner was run with details from bottom to top as follows: 35 its. 17.93# N-80 Hydrill flush joint liner with Baker differential fill up shoe and collar on first joint. Ran two down cups on stinger inside liner.. Hung liner at 10,999' top at 9489'. Pumped 5 bbl. water and 500 gal. CW wash, ahead of 300 sax class G cement w/3/4'/*T.I.C. - slurry wt. 118-120lb/cu.ft. Started to pull out, moved pipe 4'. Ran Dialog and found pipe free at 8250'. Backed off at 8248' and pulled out, leaving 1241' of 3 1/2" drill pipe in hole. Top of fish at 8248', bottom at 94891. 5/30-6/13 Fishing for Cemented Drill Pipe. t Made up and ran in with washover assembly. Washed 8248'/8300'. Pulled out and left washover pipe in hole, top at 8201'. _ Ran in with Bowen spear and jarred washover pipe loose, recovering some. Ran washpipe assembly and washed 8248'/8300'. Ran in with drill pipe screwed into fish at 8248' and twisted off. Pulled and recovered 42' 3 1/2" drill pipe, top of fish at 8297'. Ran in with 6" T3A flat bottom mill and milled 8296'/8336', 40' in 29 hours. Ran wash pipe assembly and washed 8336'/8377.'. Stuck wash pipe w/shoe at 8377' top of wash pipe at 83Q7'. Jarred on wash pipe for 11 hours without success. Ran 1 5/8" O.D. Dialog sinker bars and jars inside 3 1/2" D.P., stopped at 8338'. Worked sinker bars, un able to get into fish. Pulled Dialog assembly, 9 backed off safety joint in wash pipe and pulled out. Ran 2" x 4 1/2" -TS tapered mill and dressed out inside 3 1/2".D.P. Ran 1 5/8" O.D. Dialog sinker bars to 9490' t Could not get through stinger on Burns liner setting tool. Ran 4 1/2" TS pilot mill and dressed off top of fish at -8336'.. Ran 38 Its. (1172') of 1 1/2" tubing on 3 1/2" D.P. with tapered mill shaped on bottom tubing joint. Cleaned out 9482. to 9483'. Pulled out and reshaped bottom joint of tubing to 1 1/2" O..D. flat bottom mill.,,.;.Cleaned out 9483' to 9499'. Stuck 1`-1./2" mill at 9484' while pulling off bottom: Ran.two Dialog string:shots to vibrate pipe, no success. Ran ` Dialog free poa.nt, stopped at 8320'., worked.;to 8342'. Tubing bent at this point. Pulled 180,0001t,;50,00011 tension on tubing, pipe broke free. 5 1 • } - 9 - k s 3 OPERATOR Mobil Oil Corporation WELL NO. Granite Point State #31-14 DATE November 1, 1967 FIELD Granite Point Sec. 14 T ION R 12W S,.M. Signed C. C. Woodruff Title Area Engineer Date 1967 Could not pull Dialog, pulled line out of socket. Pulled out of hole recovering 2 joints, tubing and freepoint indicator, leaving 36 joints tubing in hole. Ran in and found fop of fish at 8374', could not screw in', pushed fish to 8386'. Ran 1 1/2" Bowen tubing spear, unable to enter fish. Ran in with 3 1/2" D.P. and 6/8/67 reverse circulated for 6 hours. Ran a 4 3/4" impression block and took impression of 3 1/2" D.P. at 8336'. Ran 65' 1 1/2" tubing with M.S. guide spearing into 3 1/2" D.P. Found top 1 1/2" fish at 8386'. Ran 2 x 4 3/4 guide sleeve over 3 1/2" D.P. Ran 1 1/2" spear into fish at 8386'. Spear pulled out of fish at' 190M lbs., no ze�jPv??��ry. Reran same set up with no recovery. Ran die collar on 1 1 /4" D.P. - PIA .-Ie -up fish 8386' ' to 837,6' lost f ibh. Screwed on to fish with die collar and drilled up to 83.76'.., loosing fish for second time. Repeated 6/12/ operation with no success. Ran'die collar 2.81 x 4 3/4" O.D., 2 1/8" x 3/4" I.D. .taper. Recovered 31.34' of 1 1/4" pipe.- Reran, could not get over 1 1/4" pipe. Reran 2 1/8" x 1" I.D. taper, could not get through sleeve on 3 1/2" D.P. Reset sleeve. Ran impression block impression showed to of pipe split at 8352'. Milled P P P P P over top of fish and recovered 31.70' of 1 1/4" D.P. Ran impression block to top of 1 1/2" tubing at 8386.': Layed down 3 1/2" D.P. and 4 3/4" D.C.'s. Stripped out BOP and installed Christmastree. Suspended fishing operations at 5:OOPM 6/13/67. 7/1 -7/13 Resume Fishing Operations to Retrieve 3 1/2" D.P. Ran 2 1/2" O.D. x 2 3/16" I.D. x 1.51' feeler sleeve and worked on top of fish at 8386'. P.O., no marks..of feeler gage. Changed feeler sleeve, reran and worked over fish 8386' to 8387'. P.O. and run in with 2 9/16" x 1.33' die collar. Screwed .into 1 1/2" fish at 8386'. Worked free. Ran Dialog feeler to check 1 1/2" fish at 8386'. Screwed back into fish. Ran.fspud bars and cleaned out 8432 to 8634. P. 0. and ran left hand die collar on left hand tubing. Attempt to screw into fish without.success. Ran tapered top with outside skirt. Skirted end of fish, working fish with 15'.free travel. Backed off 2 7/8" tubing leaving 2 jts. 1 1/2" tubing Iand tapered top in hole. Ran in with 1 joint 3 1/2" D.P. Bowen jars and 2 7/8" tubing screwed into fish and jarred. P. O. recovering 2 jts. 1 1/2" D.P. and 1 tapered top. Top of 1 1/2" fish at 8386'. Ran in with left hand tapered Wp and �—� " attempted to screw into fish without success. Ran TS skirted mill and milled � 1 1/2" tubing f617; -hours. Ran HE pulling tool and pulled on washover pipe with Dowell pump.- Pulleid oose with 7000 psi. recovering 1 jt:--i33'-*washover.pipe. '.' Top wash pipe At"8341',. Ran.l 1/2" spear with 2 1/2" skirt. Stopped on 3 1/2" D.P. sleeve at ,83,361. ' Ran 5-3/4" Bowen socket with 4 3/4" grapples and recovered sleeve. Re -ran sleeve. Ran 1 1/2"Bowen tubing spear with 2 1/2" skirt, and attempted to spear 1 1/2 ".tubing with no success. Ran TS 2 1/4" inside mechanical cutter and cut } 3 1/2" D.P. at 8364. Ran Bowen 2 5/8" spear and attempted to pull 3 1/2 D.P. - 10 MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR Mobil Oil Corporation WELL NO. Granite Point State #31-14 Date 1967 7/14-7/20 DATE November 1, 1967 FIELD Granite Point Sec. 14 T ION R 12W S.M. Signed C. C. Woodruff Title Area Engineer without success. Ran 6" Bowen spear and unlanded 7". casing. Ran Dialog free point, casing free at 5200'. Cut casing -at 5200', pulled and laid down total of 5190' 126 jts. Junk left in hole - see attached diagram. Setting Cement Plug to Abandon 31-14 RD -#l. Cement in job #1 - Ran open end 3 1/2" D.P. to 5230', pumped 50 cu.ft. water followed,.by 68 sax class G cement, 5 cu.ft. water, 203 cu.ft. mud. Pulled to 5000' and backscuttled. Cement job #2 - Pumped 50 cu.ft. water followed by 100 sax class G cement plus 10% sand, 5 cu.ft. water and 189 cu.ft. mud cement slurry wt. 120#. Laid down 3 1/2" D.P: and picked up 5". Ran in and tagged firm cement at 575' Cement job #3 - Ran open end 5" D.P. to 50001. Pumped 50 cu.ft. water followed 10 by 114 sax class G cement with 3% CaC12 and 10% sand and 10 cu.ft. water. Dis- placed with 442 cu.ft. mud - cement slurry weight 1181P. Cement job #4 - Ran in and tagged cement at 4904'. Ran open end D.P. to 4904'. Mixed 30 sax mica and 6 sax nut plug, followed by 50 cu.ft. water, 36 sax class G cement with 3% CaC12, 10 cu.ft. water and 450 cu.ft. mud, cement slurry weight 118#. Ran in and located cement bridge at 4485'/4490'. Ran in to 4742. W.O.C. 18 hours soft cement 4790'/4792'. Located hard cement 48451. Cement job #5 - Ran in with open end D.P. hung at 4845'. Pumped 60 cu.ft. water followed by 50 sax class G cement with 3% CaC12, displaced with 18 cu.ft, water and 450 cu.ft. mud - cement slurry weight 118#. W.O.C. 20 hr, soft cement at 4781'. W.O.C. 4 hours, would not take weight to 4823'. Cement solid at 4845'. Cement job #6 :'.Ra ''..in open end to 4845'. Pumped 50 cu.ft. water followed by 100 sax class G ceme'ht with 3% CaCl2 displaced with 1.6 cu.ft. water and 435 cu:ft. mud W.O.C. 30 hours. 'Located.top at 4767', cleaned out to 47.77'. W.O.C. 4 hours. Found soft cement at 4777', cleaned out to 4782' cement firm. W.O.C. 8 hours OPERATOR WELL NO. Date 1967 7/21-8/12 8/14 8/14-8/24 8/25-8/27 MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL Mobil Oil Corporation Granite Point State #31-14 DATE November 1, 1967 FIELD Granite Point Sec. 14 T ION R 12W S.M. Signed C. C. Woodruff Title Area Engineer Tested with 700011, broke thru to.hard cement at 4799'. Polished of plug 479,9'/ 4805'. Drilling off Cement Plug for .�1-14 RD/t2, Drilled '.4805' "/9593.. Ran Dynadrill with 8 1/2" bit on -5 "D.P. and drilled -4805'/4950'. Ran in with regular drilling set up and drilled 4950'/8151.'-. Ran in with Dynadrill and drilled 8.151'/.8215'. Ran in with regular drilling set up and drilled 8215'-/9593'. Running Schlumberger Electric Logs. Ran the following Schlumberger wireline services: I.E.S. log 4788'/9609'.. Drilling 81/2" Hole 9593'/10,191' TD; Prepair to Run Casing. Ran in and drilled 8 1/2" hole with a regular drilling set up 9593'/10,191'., Circulated and conditioned hole to run 7" casing. Running and Cementing 7" Casing at 10,191' 10,205' of 7" casing was run with details from bottom to top as follows: 25 its. P110 X -Line 291, includes Baker differential collar & shoe on first joint at 10,147'. 1 jt X -over P110 8 rd. long collar to X -line pin 291 9 jt N80 LT&C with special clearance collars 291 57 Jts. N80 LT&C with special clearance collars 23# 1 it. X -over N80 seal lock collar to 8rd long pin 38 its. N80' seal lock 231 1 jt..X-over N80 8 rd. long collar to seal lock pin 23# ` 24 its . =,110 LT&C 261 86 its. N80 LT&C 23# 1 it. N80 LT&C 2911 2 jts. N80 LT&C 23# - 12 - MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR Mobil Oil Corporation WELL NO. Granite Point State #31-14 DATE Nov--mber 1, 1967 FIELD Granite Point Sec. 14 T ION R 12W S.M. Signed C. C. Woodruff Title Area Engineer Date 1967 The casing was cemented at 10,191' with 216 sax class G cement with 3/4% T.I.C. preceeded by 10 bbl. seawater. Cement slurry 105# to 1171', was displaced with 2186 cu.ft. seawater. 8/28-8/29 Prepair Hole to Run Schlumberger Electric Logs; Perforate for WSO#l. Laid down 5" D.P. and picked up 3" D.P. Ran in and tagged top plug at 10,116'. Cleaned out plug and hard cement to,r10,146',-float collar at 10,147', and hard cement to.10,178'. t Mixed salt water ,to 741f+/ cu. ft. Ran the Schlumberger gamma ray -neutron log, cement bond - collar log and f Sperry -Sun gyro survey. t Jet perforated 4 1/2" holesat 9945'. t . 8/30-8/31 Running W.S.O. Test #1 and #2; Squeezing 7" Casing at 9782'. 3 Set a Howco hook wall packer with 5/8" bean at 9900' with perforated tail pipe to 9913'. Opened tool for a 1 hour 10 minutes test. Had a very light blow throughout test. Reversed out with no formation fluid recovered. Pressure charts indicated 1 no formation fluid entry. Jet perforated 4 1/2" holes at 9782'. Set a Howco type C hook wall packer with 5/8" bean at 9743' with perforated tail pipe to 9756'. Opened tool for a 2 hour test. Had a light to medium blow throughout j test. Reversed out, recovering a 3500' rise of gassy oily emulsion with some water. Set a Baker model N bridge plug at 9832' and tested to 3000 psi.. Set a Baker model K Mercury cement retainer at 9624'. Pressure tested holes at 9782' with 5000 psi. P could not squeeze. t i 8/32-9/2 Recementing 71' Casing; Running. Schlumberger Temperature Log, Perforated 4 1/2" holes at 9110'. Changed salt water in hole to 851f mud. Circulated through perfs. at 9110'. k r . - 13 - E MOBIL OIL CORPORATION HISTORY OF OIL OR GAS WELL OPERATOR Mobil Oil Corporation WELL NO. Granite Point State #31-14 Date 1967 ,9/3-9/4 9/4-9/6 9/7 DATE November 1, 1967 FIELD Granite Point Sec. 14 T R 12W S.M. Signed C. C. Woodruff Title Area Engineer Set a Baker model K retainer at 8901', Pumped 336.sax class G cement preceeded by 10 bbl. seawater, displaced with 385 cu.ft. seawater at'a maximum pressure.of 3000 psi. W.O.C. 9 1/2 hour. Ran Schlumberger temperature log,.locating top of cement at 8200'. Running W.-S.O. Test #3. Ran in with 6" bit and drilled up cement retainer at 8901'. Located top of cement at 8971', drilled.cement 8971/9095. Jet perforated 4 1/2" holes at 9085.'0 Set a Howco type C hook wall packer with 5/8" choke at 9049' with tail pipe to 9062'. Opened tool for a 1 hour test. Recovered 2 bbl. gas cut mud and 0.7 bbl. water and mud. Initial flow pressure = 116 psi., fi 218 psi. nal flow pressure Drilling out Cement Retainer; Perforating for Production. Drilled out cement.9095/91101. Drilled out model X retainer at 9624' and model N bridge plug at 9832'. Displaced.drilling mud with 75# saltwater. Rigged up Schlumberger and perforated 7":casing, interval 9140 to 10 1.9.0. Total feet of perforation, 405'. Running Completion Equipment. Ran 312 its. 3 1/2" tubing to a total depth of 9716', with an Otis H d. string). g completion g) RH packer set at 9067' (see attached diagram of com letion y . Set packer with 4500;,psEi. Pressure tested casing annulus with 1000 psi., packer held 0.K. s' Started well flowing at 1:30 PM. Rig released at 12:00 Noon 9/7/1967. - 14 - ; i - Form P-3 Subndt "Intent REV. 9-30-69 & "Subsequent .STATE OF ALASKA OIL AND GAS CONSERVATION. COMMITTEE in LDIRicat� C. GEOL T—C. ENG __ SUNDRY NOTICES AND REPORTS ON WELLS 2 ENG I� (Do not use this form for proposals to drill or to deepen 3 ENG Use "APPLICA'T'ION FOR PERMIT-" for such proposals.) 0[L CA5 ENG B _ WELL WELL ❑ OTHER _c 2. NAME OF OPERATOR Mobil Oil Corporation 2 c_roi 3. ADDRESS OF OPERATOR _ P. 0. Pouch 7-003, Anchorage, Alaska 99510 REv R 4. LOCATION OF WELL At surfaceLeg 1, Conductor 5, Granite Point Pla _�.. L.. SEC ER: 23621 S, 12581 E, FNW Corner Sec. 13, #;— - R12W, S. M. 13. ELEVATIONS (Show whether DF, RT, GR, etc: KB 1061 (MLLW) CAL CODE LEASE DESIGNATION AND SERIAL NO. 9�1- ADL 18761 IP INDIAN, ALLOTTEE OR TRIBE NAME UNIT FARM OR LEASE NAME Granite Point WELL NO. Granite Point #31-14 D. FIELD AND POOL, OR WILDCAT granite Point Middle Kenai 1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 14. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT Or: TEST WATER BRUT -OFF PULL OR ALTER CASING WATER SHUT-OFF REPAIRING WELL FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING _ 39MOGYa ACIDIZE X ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* REPAIR WELL CHANGE PLANS � (Other) (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. In the subject well, extensive formation damage occurred when the packer fluid was dumped, on the formation while pulling dummies out for running gas lift valves. We propose to acid.ize with ultra mud. acid. PROCEDURE 1. Test tubing at 5000 psi surface pressure. 2. Acid.ize with 30,000 gallons of ultra mud. acid, in 6 stages, using unibead.s for diverting. 3. Return well to production. j D1V4`alOh1 Gr 00 Jil c 1-1 r 16. I hereby cert 7w- (Thin r Qoing is tru SIGNED space for State officeAse.. /-00, APPROVED BY CONDITIONS OF APPROV , IFANY TITLE Division Engineer DATE .AD -r -i 1 P6I,—].�72 TITLE See Instructions On Reverse Side DATE /f 7�' Approved Copy Return,&-! Form P-3 , REV. 9-30-89 Submit "Intentions" In Triplicate V & "Subsequent Reports" In Duplicate `"_. CTATG n,t= AI A C V A - OIL ANb GAS CONSERVATION COMMITTEE 5. API NUMERICAL CODE SUNDRY NOTICES AND REPORTS ON WELLS 8. LEASE DESIGNATION AND SERIAL NO. (Do not use this form for proposals to drill or to deepen ADL 18761 Use "APPLICATION'FOR.lPERiVhT--` for such proposals.) I • 7. IF INDIAN, ALLOTTEE OR TRIBE NAME OIL �yj GAS WELL 1"! WELL OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Mobil Oil Corporation Granite Point 3. ADDRESS OF OPERATOR 9. WELL NO. P. 0. Pouch 7-003 Anchorage Alaska 99510 Granite Point 1-:L4 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT At surface Leg 1, Cond.uetor 5, Granite Point PlatformMiddle-Kenai 2362' S, 1258' E, FNW Corner See. 13, TION, , (BOTTOM HOLE) 11 OBJECT R12W, S.M. VEM 13. ELEVATIONS (Show whether DF, RT, GR, etc:. KB lob' (mnw) 12. PERMIT NO. 1 66-56 L;fteck Appropriate box To inc9tcate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSDQUDNT REPORT OF: TEST RATER SHUT-OFF PULL OR ALTER CASING WATER SHUT-OFF REPAIRING WELL i FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ABANDON* ACIDIZING X ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) ,Other)(NOTE: Report results of multiple completion on Well .:::i_ - Completion or Reeompletion Report and Log form.) 15. DESCRIBE I'ROrOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and ;fee pertinent dates, including estimated date of starting any proposed work. The following is the subsequent report of the acid, job performed on May, 1, 1972: 1. Tested tubing at 4000 psi. 2. Pumped.4000 gallons of acid. dispersion through tubing and simultaneously loaded. annulus with 225 bbls. of diesel. 3. Pumped. 5000 gallons 12-10 mud acid.. 4. Pumped. 2000 gallons 2-% HCl with 7% U-66. 5. Pumped. 1000 gallons 0' 0/- HC 1 with 500# J- 207. Repeated. steps 2, 3, 4, and. 5 five times, omitting step 5 in the last treatment. 6. Displaced. last treatment with 50 bbls. solvent B, followed by 40 bbls. diesel. 7. Commenced. gas lift and. returned. well to production. 16. 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H 'FROM .1, ; t180Ci i, � f � FT ' TO 10190 ° r • a SURVEY PT y- V -s. ,. -�� P a' '' �7 ; k. rysa t4 fug i�� -!Y '� �:a, r 1 � S a -y i:':.Fa.P..r :a- -7:. - ;essF ., ,4. .t a -..i` T i' •;t t .... .asS„?, ..tai w1 n +K}, -R y 'S"xr":•$r111 tty 'tc, .:: ,-,• }t=.--ar, °L,'•''+r .k',,t'{�d -' r:Gran t.e .-Point State l�Z ,. . ,LEASE• . a w y r : �, 11 ', �� A . + t Fr. a== F t t yFe_.�y y; k t z Y -a ir., 1 fir• r A' nr , r Jip : i'� f r i`. i� .:'{n ^` t 'R. fr�>; +' 'i:�' d. 4.;i a t% c:,z� �a x y x-v� rA..uyafs y x. 1.�:� f, r� GrantePciint -x _71 11, R .; ..��ar, ;, ,;� . h FIELD ''11 , , . d° �'.� i:3 : gi t s' ,;:,oto 3: i r '_ �., a.: k v!i"i *-!,.?ul`< •2'-. a..c:.:.{.i �.. . iC ,Y... s ` , COUNTY/PARISH Kenai ;Penn. Borough 'L } gTATF p '. `� 11 £nc; .�..' y _: r? .R'-` ,°""•F�J k { f ekr i y "x} tb '2•%d••, a`{F xTs "3e 'J{+�_j� l,. ,,F? ,Yz # h: a `� --` , 8 28.7 x1Y :,Oe .No SU-3-� 1 0 - . Y ' DATE OF SURVEY +" h - ' i A t 'f :'ate L� i I; �• ,y-t�',F a _''✓ ei`. f t $ ,� t . T rk t� Y .tty2; h Y''11 2-j ifi1. i .'i b#Fv f4 i , .,j. 4r, p #_Anchoragey� `A-laskal, f, R + tYZyi,fj p �` _ Al:-FICE• r , ,,. _ A ,r ' `4� f :k k �.:js %s $k ;14 ,vr '' .1 .• `"_.c pE” } s. tF <� r'' Her,. • - t, I :It' . -4 62,.: I!" ,av '_ i l�1 .Jtr, ,,:, ` .; _ Y x E c;?'i S r1. y "3g Z ; §'.r >, J '#� � i Sys t `} i x:i': '� try •t -Y( S { £f { U4 .,: .z n C+� x G , s y,��yy«r�.. ^ ha !' :: - _ - ,:• ': S. • "`� { :Yy u ? � 'ice+{. �� - � �r �`'�`'`� .1r'• �'.�� - - /. rii•`Y} JUKVt_ Y '..'1 HtSULH 1.,1UtV 5htt t t N �)j / n M/^ O! L com P4 �� SHEET NO. 1 CUSTOMER-- -MV j / A T T' y SURVEY _ �,• ' E �,�.. r w N T/ WELL NO. _� J • J. �_t_. _—.. 4 y j :=; JOB NO -- --- — _ — SURVEY g — FIELD tTI..�--_[/I'� / sxk�,� F S — j c� s";s . '�;"�z rzq� �yy��i , a �rtn zrys e5i�,fi, dcc, x� DAT E A . MEASURED T DEPTH VERTICAL ,DEPTH ANGLE _:fi�.�r�:: l Y CO RSE x L'r i x�z_ai a ,...,sit T tY DIRECTION�OF`tNCLINATION'* ; ;, _...:iYt ,... r.: MEASURED COURSE DISPLACEMENT TOTAL DISPLACEMEN.-T!---- CORRECTED TIME ... ,OF `INCLtnE ATtONy - ; -V frOE�K X;>':ti COURSE _ TOTAL :! COURSE .;''..-TOT 4L_: .; .:. - „-' -e ?,ai z a���q OBSERYEU �r� -., '•yra` v .` yl r _ CRR ; Hs,"'r*r^'�=51;° k �� 1s tea.,"• �, CO,RRECTED xG'3'2•C F' " t.. . NORTH ,.SOUTH - F'.. ..EAST WEST .. NORTH SOUTH EAST WEST R. - - !'. : .,-- .rR Y v.:.4 cy T:. ,..61"''' j<.1•-•t.,t,''. H1{`"SrH•'E°'ras'� a ^� x Vit• 1 _ •____+ _-_ .�_..__ J- - MZ { C.yYA 7::'kt arrr S' 3.'• �. / O 440,29 Wa «�.3x e- ST: _•-:•{ ° Ol�O:: .-6+I � �� 40o 4.7oo /Vit�Lv':;.: 7���%" 60 654,fid t vi 0"UJ2v �. �- , /o 7 3 s -]re{ a3l 04,)l oo 1 �':�• �'•�.: 56f,1G _-._...- 1f `(� 1 �!-'n:,.�.. p.: a, :-a+aly .[j, �•abt..SL 'h.'A'H . I..' � '. �: " .. fi; p DO S � C� ' .,Puna%' - '). r , ��', '. , � 'V .-.. 4. .. .. 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Y: SURVEY .� ' FIELD4 "�� �%-�%kz'�d /� r;: DATES 1.-. r, : �# . .. 'a.. •..,seer. - ' 0.�. ,;�'...- 2•':'::, ^ss '^-..... t __ ♦ .. ,. "} ._ - ,Ft'.. - . ....-..- i,,-.._. .!.. ...,�� ,�' ..:i.. i. -1.V-n y- .S.e.' L...: b.-.. -.:.. ;✓,; .a.. _..., .::. _ - _ , .,y . ..srs,.s. fi'! ...._ it ..+_ -. 'CORRECTED •..; :. A!!E/tSU EOE' to ,N il.��! 41w4 ;r.r??.GY:IRy •a'.:_ :�_3-'.: a,.: Ri {;.'ANGLE' YER I,C�/„►-4�DE ,TN c *§s:, .t_, ^9. /.,, ._OF � �:.C�urtSE - DIRECTION OF INCLINATION . MEASURED COURSE OtSPLACEMENT _ -w ,c�sl.; TOTAL DISPLACE { � -, � x ,. ', 'y; '?.f�::x.�l.•?,,.. •ATIOPt -. »'... 7 ;a7,yr,f:,INCLIN OOURSE �':TOTAL'`� ` '_'.:- [a.s._,a CO0RSE��'TC)TAL: .s. L. .-';• X^-t,x. a'h-' OBSERVED O E - GORFt - ORREC.T D C E N RTH ? SOUTH O SOU 4.'' EAST WEST - _T NOR H r ;SOUTH `'•'`r� EAST°r?, 'ES ° r.i y.�•. _ a 2' - y o -� �U o `�79 � � .� �•: I.7,7S. _ ^ x:•4.1 �' 2 3 d �✓ , _ G.� =moo�_7So-a� ¢L/•_ Ig _. _-__ /� _.�:.: 1 /y/� �._ 5.3;:70.. 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' m,.. r �/,.. x s . / / 1i 1 X751 5 . .,. ... .. ,... ,rt,µ ...,. a. ...,,, .,E•"11.,.r. .. .. .,, .. .. f .,.:.:.: - ,, "': '. , .... a.:: -::' .,. �: .. -. ^,.. ..'l..' .... .• :,: > .. ... a '.W".,: ... .a _. a. v. .:Y.t� - ONE t3Y, .,.Rs7. t . 4. r /A ` tat Min. tad min. Ticket �►r Flaw Time n, 1'; Hour t ti: z§ f•' a �.� t (A Date - ` ' : 8•-29 67 ` Number' " 464119- lst _ Min. Ind " Min. " ' a Closed 1n ": x . Kind '" Hatlibarton Press. lme' gt `` of Job Water Shut Off District Anchorage Pressure Office v H Reodin s Field ' Corrected Testers ' a B.. Witness' L Hammerson r. CrJ �sz . � o Depth `` `Blanked Drilling y O Top Gauge 9889 Ft- no oit Contractor SANTA' FEDRILLING SM o BTx Hour r` p H To P.R.D. Na. 1489` 24 `'` Clock Elevation Packer 9899 w v, Initial Hydro Total . Bottom H Mud Pressure 4824 Depth - Packer Initial Closed Interval Formation in Pres. ` Tested Tested 1 Casing Top 9945 Initial Casing or Flow Pres. 2 Hole Size : Perls. Bot. 1 w Final Surface Bottom -- Flow Pros. - ;, , Z Choke - Choke 5 $ o �- '. .`' I.D. LENGTH Final Closed Size is Kind Drill Collars in Pros.' - Drill Pipe 3 13.30 Above Tester Final Hydro 4824 Mud Mud e Mud Prenure Weight Salt water 76# Viscosity Blanked •F Est. Anchor Size Id Depth Ft. Off . Temperature •F Actual x ° �• c Cen. Gauge is Length OD BT. '.; Hour' Depths v Depth of ' t Ft. P.R.D. No. Gook Meo From Pester Valve 9885 TYPE AMOUNT C Initial Hydro' ;_ ` Depth Back Mud Pres.} Cushion`" Ft. Pres. Valve 9880 Ft. Initial Closed in Pres. Recovered Feet of r` Initial s Flow Pros. 2i Rocove od Feet of © c Final 1 N, Flow Pres. �. 2 Recovered Feet of C ►�, G t k t a 3 Final Closed i r in Pres. R@cover@d Feet Of - Final Hydro k . a Oil �r:. ata r' = s _, .Water .rj,� a *`} Mud Pres. " A.P.1. Gravity rr $pec. Growl Z as e r' = It '�Bionkad.r. a 5urface DepthGn Bot. Gouge 1 Off Grovix Pressure° �' psi tY_'" y Y. ? >+ `gyp?� a • ou Tool �,, �_ k. Tooi•� ." P.R.D. Ada. £ f Cloak Opened <+ `1.45 PM r P.M.{ Closed , a 2.5 5 P.M. Initial Hydra lL Ft i� ' j. F' . , f a t y Set acker 'at ' 9899 ¢ to.. nest 4 .holes at r Mud Pres. , 48 6 7 ° Remarks P., ., r . it rp- v r #t ?klf y t aix r 'y F, InitiolClosed er' -flow >, 0 e '' lhoura �^ ' In Pres._. 994'5 -{for: wet , P n + Initial �{ Flow Pref. 2 :t - '-__4t'tC Final 1 r Flow Pres. 2 uF� F 3 d nrr * . Final Closed In Prey. , _ - s , .. t • -s -. a ' t' Y; r:• 3 =',r^ 1 'Finch H dr�i y 4867?' Mud Pres.__ 3,_=4 ,; t. 5 t>,=", e °K:. E .<, •7 : i - � A N _ ` = O� I 1 F" t�/t TI T :v'1" � A ' 2 r 5 x i Fresh Water�Corrected to 100° zt. a f a ;i t r t i t g r h k t 1 1 t ta'y.- •��� iL i, i }.reJ•.ar ti.a...p�wsw Y »f bJ n5 t:N •,L'C r h � kcwA? x 1r' . 4Y iALI +r 1 a a c�aaa litY '° tri Kfi Iwlr*Yv�+e�*a�trrw►sr,sr.r�wel+w '.'"'"""..'':,,..'.�"""�'"'"�.' , s OWN; .i Ij t,. a f t t ' ., l I WWI �" � I�? t S t f. - - ,•. 4-. 4. fq` J', it vY s y ,rain t r�4 r `A�_ VFrb u�sr{ ,r f 'I - �rir i�,e :iAakv.. trI t .i ir"5'T +r. r .j 6rC.G'it �F Z -. •i '�, a i!'��^ f ,t ., - ='+3R.u.i�a.x'4'"'r'""4t911"i' ��,�r.rs�g't- rra.r�,nr- ,<��f+o�'rxre3'�,kr• s�+,sa s�� ie �� „��� z '+� w + j dfy. list's.� r2; { ff` y ' rT 1 i �♦ } ^.17nr1 e'`,''ai L e`�•, 4' ¢ 3S�i �Kh. r. v, ! 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Curr Witnes$ "„ M H Interval ` '.Q Formation Blanked i.,� 1 Sci 4" 31'� ryii Fes{ k '' A� P•!_ G[ �j }i •Drilling"�a�y sac? �:,.. �,s n c._ jrx t :i r"`t •ear rk,P i3C�� i `' ;•• 1 9039 t- : ta. no Contractor�'x'=`'SANTA ` FE " DRILT;ING • , r � - =j* "f . ' Sm :s z Hour .... { � � �. y � '. a b ' 'e4•' 1 r +- f � G. sr-_ r 1 � r ;.,,Top O 1489 24 'Clock" :E�evaiion' , :(° ''{ 4i f 4 Packer" 9049' To. Perfs. Bot. 9085 ='Mud Pre 4896 F'OIRMATI OWTEST t DAi-A� �7ft .a. •,�/ IL.i//V./1v1/.,. vu1 ru,gv rl�rlulv//��. /V ''w1 , Fresh Water tCorrected tb'A 00 � ai, i i �F �.. y, ':rte •f it z�. � t�. t i a• i F r t r" F < -"-,t " y£ •' �.� # i -a fa- # `-z�.1 -} �' A. r s '2r F 2 fti 2s'�` ` i S f g '°",Y r't,AuF ;}r ✓z k ! 4 ! ,. Y: _: ia„G�. '_1^sk� "<°.[' ;{. �., r �s •'"iti ��� � #„i. �^' r§x. t'� •,t1 �.4.f�j' 9 n- R .t �> �� '.'f ,� s �'` ���ri�a'} _�. �,x �`4 �� �p t - 7•�� `} r `'fir>t?�. }`siH;:xi { ,. , s i 134, 2 ;[ W<".r 55 { �:.:Total X ,ark u P 4 {i ='..t �t ; 35 ( .,Bottom.- � `", � ,. V €' 2 . .:'231 "jr" )x�1 aif�� }• � ) h VI r ...rS 4922 Y Depth"`. '" r. , Packer ,F r Interval ` Formation Tested,. :s Tested 1Casing or �` ' n :: 'Hole Size - 7 t r ;'Casing r To. Perfs. Bot. 9085 I 2 _ Z 10 1= `' Sarfoce r Choke e.. '.' B ofeom Choke 5 8 ID 0 2 223 Slse' is Kind` } :, ` Drill Collars I.D. - LENGTH Drill Pipe 3 13 .30 Above Tester _ ` Mud Mud -� ' 4909 'r Weight - , 82 ;' Viscosity 45 x _ Blanked` ;Temperature OF Est. Anchor Size lbY�+ &•Length OfD � 0 o a Z Ft. ::, Off •F Actual 2 7/Er 6 s .. Hour Depths Depth of ` Dock Mea. From ' 'Tester Valve 9035' Ft. , TYPE AMOUNT Depth Back Cushion none Ft. Pres. Valve 9030' Ft. Recovered 390 Feet of mud o t Recovered ` Feet of - .2 Recovered Feet of p o e 0 3 2 • ' Recovered Feet of o oil ; .... Water z A.P.I. Gravity Spec. Gravity Blanked Gas., Surface 1 9059 Ft. yes ' Off Gravih► Pressure ` R=1 G Hour Tool :"`. A.M. .Tool A.M. H 1460 24 ' clock Opened 9 OQ AM P• " Closed 10 0 00 AIA P• • 495 4Remarks }s Set packerat 9049 to ` test 4 holes ' at 9085' F=Flow `l hour. a ='Mud Pre 4896 F'OIRMATI OWTEST t DAi-A� �7ft .a. •,�/ IL.i//V./1v1/.,. vu1 ru,gv rl�rlulv//��. /V ''w1 , Fresh Water tCorrected tb'A 00 � ai, i i �F �.. y, ':rte •f it z�. � t�. t i a• i F r t r" F < -"-,t " y£ •' �.� # i -a fa- # `-z�.1 -} �' A. r s '2r F 2 fti 2s'�` ` i S f g '°",Y r't,AuF ;}r ✓z k ! 4 ! ,. Y: _: ia„G�. '_1^sk� "<°.[' ;{. �., r �s •'"iti ��� � #„i. �^' r§x. t'� •,t1 �.4.f�j' 9 n- R .t �> �� '.'f ,� s �'` ���ri�a'} _�. �,x �`4 �� �p t - 7•�� `} r `'fir>t?�. }`siH;:xi { ,. , s i 134, 2 ;[ W<".r 55 { V €' 2 . .:'231 "jr" )x�1 aif�� }• � ) h VI r ...rS 4 InO - t �:•'� y. 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I ta --=w , t - i77 1 E 4F F.I f w .. 1 -':12 526ti .! i <..HtH .1•i C tv' ✓. ,. it: i•. �- r KEUFFE-L ...-�`' —•Liz 10 7t 10 TO THIO INCH is a (' ` Form No. P-4 Effective: July 1, 1964 STATE OF ALASKA LAND OFFICE OIL AND GAS CONSERVATION COMMISSION LEASE NUMBER LEASE OR UNIT NAME LESSEE'S MONTHLY REPORT OF OPERATIONS Alaska Kenai Granite Point State__ Borough ------ Field ------------------------------------------------------------- The following is a correct report of operations and production (including drilling and producing wells) for the month of --------- March ----- 19 67 .4 jent's address ______ P :_ 0. Box 1734__ .Company _ __ Mobil_ Oil _ Cor orat io ------ Anchorage, Anchorage, Alaska ---------------------------------------------------- ------ - /j / t --------------------------------------------------------------------------------------------- Signed __Sw _a__- Phone -272-2555 -_______-_ .I9ent's title _Area_Engineer ----------------------- Ssc. sI�D. Xs or TWP. WELL RAIzc3E NO. DAYS P8OVU08D BARRELS Or OIL _ QRAVrrY Cv. FT. or GAS (In thousands) GALLONS or GAsomm RECOVERED BARRELS OF REMARKS WATER (If (If drilling, depth; if shut down, cause; none, so State) date and result of test for gasoline content of gas) Granite Pont tat 31-1 TION, R12 W, S.M.(T.D.) NW/4 of NE 14 of Sec. 14, Drilled 12 1/4' hoe to 8804'. Attempted to free DP. DP arted at 8348'. Attempted o fish cut DP & DC's. nsuc essful. B to 480 )1 w/250 cu.ft. Class "G" cement. Sat 9 5/8' casing at 4783' and cemented /500 sx lass "G' cement. Drld. 8 1/2' hol a to 799W. Drilling as of 4--l-67. NOTE.—There were No ....- runs or sales of oil : .................. No . M cu, ft. of gas sold; ................ No runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE. --Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, Mnl"fsro s directed. -> IV/ APR 12.1967 DIVISION OF MINES & MINER&3 ANrrwnper_r Form P-3 STA JF ALASKA SUBMIT IN TRIM' ITE* Effective: July 1, 1964 (Other instruction. n re - OIL AND GAS CONSERVATION COMMISSION a. LEASE DESIGNATION AND SERIAL NO. . Sja$te ADL 18761 SUNDRY NOTICES AND REPORTS ON WELLS: -e• IF INDIANt-ALLOTTEE OR TRIBE ,NAME (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT—" for such proposals.) 1. 7. UNIT:AGREEMINT NAME OIL ® GAS �. WELL WELL OTHER i* -- 2. NAME OF OPERATOR $. FARM --OR- LEASE NAME Mobil Oil Corporation Union-Mob.il State1 S. ADDRESS OF OPERATOR 9. WELL` NO. r, 700 G Street, Anchorage, Alaska 99501 Granite `vPoint Stat`e1,#31- 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* 10. FIELD AND POOL, OR WILDCAT: See also space 17 below.) At surface Granite -'Point ' Middle P 11. SEC., T:, B.,,X., OR BLZ4 AND - 2390'S and 1379'E from NW Cor. Sec. 13 T10N R12W S .M. eoR4. T ASE. Sec. 14; �T10N, R12W S.r (Platform) Cook= Inlet 14. PERMIT NO. 15. ELEVATIONS (Show whether DF, RT, OR, et0.) 12. BOROUGH-' 18...STATE 66-56 105.9' above MLLW (KB) I Kenai _. `r� Ala„ska 16• Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data . NOTICE OF INTENTION TO: SUBSEQUENT REPOI]i2 'OT - TEST WATER SHUT-OFF PULL OR 'ALTER CASING WATER SHUT-OFF :REPAIRING WELL `_; FRACTURE TREAT MULTIPLE. COMPLETE FRACTURE TREATMENT -ALTERING CASINO.' SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZINO ARANDONMENT*- REPAIR WELL CHANGE PLANS X (Other) (Other) (NOTE: Report results of multiple ,completion.: on' Well; Completion or Recompletion Report•'and.Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including -estimated date of starting any r proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths foail markers and zones perti- nent to this work.) • ,w Due to drilling problems and probable unfavorable structural position..at-7they =` w original target, it is proposed to redrill the well as follows: s 1. With open ended drill pipe at 50001*, set a 250 cu.ft. Class "G"' -open hohe cement plug (calculated 305' at 100% fill). WOC 24 hrs. 2. Cement 9 5/8", 40#,,N-80, LT&C casing at 4790'± with 500 cu,ft.:.Class "G' cement plus 1% TIC. (Calculated 1596' at 100'/, fill) . . . 3. Kick out of old hole in a N70OW direction and drop angle at the�i'ate'of 1 1/20 per 100' to near vertical. Est. Top pf Kenai: 8000' MD (-7500' VSS) Est. Total Depth: 10000' MD (-9500 VSS) / Bottom Hole Location: 1571_'.S & 612'W fr NE Corner Sec. 14 TION,R12W S.M.'-rl .: SIGNED (This space for F13!�/ /nS�ta#e ofDce use) APPROVED BY ' CONDITIONS OF APPROVAL, IF ANY: Area Engineer TITLE *See Instructions on Reverse Side DATE- MA le.1567 14 UIVt51UN vF MINL-5 & MIN\"P.ALS ANCHORAGE Form No. P-4 � Effective: July 1, 1964 STATE OF ALASKA LANG OFFICE OIL AND GAS CONSERVATION COMMITTEE LEASE NUMBER LEASE OR UNIT NAME LESSEE'S MONTHL 1 REPORT OF OPERATIONS Alaska Kenai Granite_ Point_ ____ _____________________ State --------------- ---------------------------- Borough - ---- ---- - ---- . Field ------ - following is a correct report of operations and production (including drilling and producing wells) for the month of -----------February'--------------- 1967--, ---------------------------------------------------------------------------- P. 0. Box 1734 _____ Com an Mobil Oil oration Jfent's address-------------------------------------------------------------- Company --------- -- - ------ --- --- -- ---- --------------- Anchorage,--Alaska--99501 - Signed ----------------------------------------------------------------------------- ----- Phone 272-2555 --_ .Isent's title Sr. Prod, gineer SEC. AND OF X Twp. RANGE WELL NO. Dere BARRELS OF OIL GRAVITY PSODaCtD Cu.FT. OF GAS (In thousands) GALLONS OF BARRELS OF GASOLINE WATER (If RECOVERED none, SO State) REMARKS (If driland depth: it est f down, gasoline date and result of teat for tasoline content; of itas) ,Tranita Po nt Eltate 31-1 14, TION, R1217, S.Ix. (T.D.) �ITW/4 o NEA of Sec. Drilla 12 1/4' hol to 810'. Stuck d ill pipe. Backed off at 8557'. Went in hole w th 0 3/4" sh pipe. Stuck wash pipe. Left one joint wash pipe in hole. Top fi h 8502'. Pulshed ish to 8517'. With open anded drill pipe at 8516', set 150 cu ft. Cla s "G cem nt plug. Drilled cement 278' -to 8350'. bandoned' fish, -icked out of old hole. Drilled 12 1/4" hol -to 876 Drilling. Electr c log runs were m de 8280'. i NOTE.—There were.............0................................. runs or sales of oil;....................0.._._..................... M cu. ft. of gas sold; 0. ............... runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.—Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding mon ,'4-mrojhVr�R�v fe 0 directed. ''�� NIAR 6 1967 VIVISION OF MINES & MINERAL3 ANCHORAGE Form No. P-4 Effective: July 1, 1964 STATE OF ALASKA ` LAND OFFICE Anchorage OIL AND GAS CONSERVATION COMMISSION LEASE NUMBER ADL 18761 !� LEASE OR UNIT NAME Union-Mobil State #1 LESSEE'S MONTHLY REPORT OF OPERATIONS Alaska Kenai Granite Point State-------------------- ----------------------- Borough-------------- - - ------------------------ Field ------- ------------- The followings is a correct report of operations and. production (including drilling and producing wells) for the month of __-________January1967.E ---------------------------------------------- ------------------------------ .i ent's address ___P Box_ 1734 _ _ _ Moi _Oil _Co-_ oration - - - - ------------------------------ Company -- f - --------------------- Anchorage, Alaska 99501 J ruction --------------------------------------------------------------------------------------------- Signed -�-�- ,---� -- ---- ------------------=--- 272-2555 __________ .lgsent's title Sr. Pro Geolo ist Phone------------------------------------------------------------------------- ------------------------------------------- SEC. AND. WELL Ds:s. Cu.FT. OP GAS GALLONS or BARRELS Or REMARKS Twp. RANGE BARRELS OF OIL GRAVITY GASOLINE WATER (If (It fig• depth; if shut down, cause; YA or No. Psoavaga . (In-thousands) GASOLINE IIOIIe, 90 State) date and result of test for gasoline content of gas) Grani a Pont tats #31 14 NW/4 df NEI/4 op Seo. 14,1 T10N, R120, S �Ma (T.D.) Drilled 12 1/4' hoe 672'/2560'. hole to 17 1/2', 6'.8'/2350'. Ceme total of 1100 ax Glass G cement. gel. f llo d b 330 sax neat cemen returris of cement ut water. Pump cement in L3 3t8" 20" annulus. Installed 3.O.P. Drilled out hard bondlog amd a Sperry S n multisho out cement 230 '/'2 28' .shoe of 13 Ran S. lum erg( --r e ectrcal logs. ,an SChlumberger electri al logs Opened 12 1/4" Lted 13 3/8", 61#, J-55 --asing at 2328' with a .The first 800 Eax pretr ated with 3% prehydrated con aining 2% calcium hloride Circulation ,d an squeezed a total Df 961 s x Class G neat .each d a maximLm pressure of 1500 psi and held. cement 1905'/2208'. Rai a Schl mberger cement sur ey. Rein talled and teste B.O.P. Drilled 3/8" casing) . Drilled 12 1/4" ole 2560'/7278'. Preparing to d ill ahea . NOTE.—There were...........................�------------------ runs or sales of oil;.............................0................ M cu. ft. of gas sold; ...............................:�.......................... runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.—Report on this form is required for each calendar month, regardless of the status of Re�ta$��j� be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding mon n s olel vide D directed. xxx:vi FEB 6.1967 2-3-67 DIVISION Of MINES & MINI:RAW ANCHORAGE Form No. P-4 .l =' STATE OF ALASKA ' OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 (J LAND OFFICE Anchorage LEASE NUMBER ADL 18761 LEASE OR UNIT NAME Union -Mobil State #1 LESSEE'S MONTHLY REPORT OF OPERATIONS State --------laska---------------------- Borough ---- - ---Kenai--------------------- Field -------------Granite--Point------------------------------- The following is a correct report of operations and production (including drilling and producing wells) for the month of----Decejnhe�-------------------- 196-6---, ------------------------------- -------------- ---- --------------------------- .ggent's address __-17.3.4________________________________________ Compa ___1 obit- i1__ r.paration.____--_____- Anchorage, Alaska 99501 ___ Signed--�-'L' -------------------------------------------------------------------------------------------------------- -----------------`- ------------------=- Phone 272-2555 _____________ jeent's title ___ __, __Produc ` _ on _ Geo to is t __ SEC. A"WELL Dere Cu. FT. oY QAs GALLONS OF BARRELS OF REMARKS (If drilling. depth; i[ shut down, cause. ya OY Y Twp. RANGE NO. PBQVVCZD BARRELS OY OIL GRAVITY (In thousands) GA90LL�iS WATER (II date and result of test for gasoline RECOVERED none, so state) content of Ras) Granit6 Point 81tatei #31-- NW/4 op NE14 o4 sec. 14,1TION, R12�, S ..�M. (T.D.) Spudded 7:OC P.M. 12-24-66. Dr lled 12 1/4" hoe to 36V. Opened 12 1/4" hole and drilled 17 1/2' hole to 667t. Ran Schlumberger lectric 1 log to 667'. Opened 17 1/21' hoe to 26" to 625". Drills 17 1/2' hole to 670' and 12 1/4' ho e tc 672'. Cemented 20' casing at 6181,with 1200 sax o Class G cement God emen returns were obtained at the urface. Cement in place on 12-28-6. Ins alle and tested B. .P. Drilled ou cement from 545' th 618' (shoe If 20" casing and cleaned out to 672'. Preparing to drillahead. 1j i i .1Ad 13 1967 ftstory OF MlINE5 & rvl,t.N'—.RALs ANCHORAGE NOTE.—There were --------------- O ......... runs or sales of oil; ......................0....................... M cu. ft. of gas sold; _ 0 . runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.—Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, unless otherwise directed. - �s� _ - rr` �k.:�" r� i `� �`�"i''�s�x kt r'r✓711 v�,�' �`�'�' ' T � -- ,�, ' 1" � �a - ��,' °'�' � •Y`..c���r�:1' yr -_ ��� '��« ` �'�'�,9'���'rl.,+�`;,w� -�i�q� �'f"� �'x.3x - �yx r • w , .y ATE' "s f`t" sj L f D y3 C 1^( Y � - rim. s cY' - 4 • �•�4r�'�'a3- 'w} i� �'�t; � 3 � 'S-.. � __ y. _Y }: I* MAD I Ab � ,, �•- �'> .axe a_ _ r w ftllili�. '°• Ate. ,,.�` K � I }.;;-t z jxf t3"AT��.`.7kiz+l�'.��r ,�> �.1�, s' t � cti�t'r - - - � ' � .� x`,; X,f ': � � fix: vC'k« N r i -, �.,�.rp ; tt- t ••s _.� Y ti 5 g a ri r k a r r c� yr R y� 'SY �1y t • ,. y s` �_�- ,�^{ a ''� 'fes _• k �''� di r�±,,,t'`r< �' x Pr` -a �, i ri' E l r : i ��a _:. �.. t-.. .. - �, F p • - r ��„ ,yam; � . •"+.� � ate" x • ,rs �. - - -r $, ,:,ems`' •''h' • ! - _:.Y.,; ^�. - s. _ �.�, i .,y 4 ,� �,, h3n .r _:.- a, t:.-',': .T�•. -1r ..�;«k.£ _ _ �� „nK:-�a. ::�. ^f _ _i. �k �Z r"-stts:`"55...- ,'!f -• �,r�;,.: '4`_�.,,�.^�� :' �z.� -. { sa-m:ith .zicrra-'uE.*"t".y�,�_ r ' t3..,:.z'ttt "-.x:"Y'tYs-=ti,rc ,r`—X � �`'�x �. �. k 'e�- .r ra �z^� -c,r -•� � _ ... •s �, a ,h_... ...._ _ t. -w:::. a.. _ vs- � -. �`'x + n"7..?'_ 's .s- 6 _t� ...:$e.-••- .,a ..-�' 'ac.+t" �} .� iC. ✓ #�v,s3;+z•`y�,i�>ny.�, .r.�;f"4'�y'��"'s'v "'X �"�s5'bk�"�;'%'!it ,31 .e� <. _t. ..-. : �... __ �''�����......'€._.. _ _�."_,.-������~.... ..,,�._. .,.,,....._.,. _ .,-.. ,. _ �.r ..,�az.��a,.s'.:-a.e.7_-ir .+,�z. r. +'.x .n« .. nf.._.=a�. ... _ ..,.. 1 l,�•�� �. �awi ..�N:!t: ._ � _..zx... .k � . - ,� _ .�_,.s_. �- e3. _0kA 612 SOUTH FLOWER STREET LOS ANGELES, CALIFORNIA 90054 NORTHWEST PRODUCING AREA F 1 ' Pr At i November 15, 1966 fI' A Mr.. T. R. Marshall, Jr. Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, . Alaska 99 504 Dear Mr. Marshall: Included are Forms P-1, applications for permits to drill two wells in the Granite Point Field, Cook Inlet, Alaska. Also included -are two $50 checks covering each of these applications. Upon your approval, would -you please certify one copy and return it to us to complete our files. We have also included a location plat showing the bottom hole location for each.one of .the wells. These wells will be drilled from our Granite Point Platform and will be deviated to the bottom hole location shown. We are.forwarding one copy of this application to Pan. American Petroleum Corporation,.the only,affected party. Please let us know if you need any additional information. FCP: jsc Attachments Yours very truly, W. G. Christensen Area Superintendent cc: Mr. A. E. Piper - Pan American Mr. R. A. Lyon - Union Oil Mr. H. H. Hamilton - Anchorage Mr. J. L. White i . RECEIVED i NOV 211966 f DIVISION OF MINES & MINERAL$ ; ANCHORAGE i , Ohl t , Form P-1 r > ( SUBMIT IN. TR• 1ATE*,.. July 64 Effective , 9 s. , _..-"Sa1Et.OF: -(Other:.,instructibne •oai, _, _ AL"ASKA _ _ . reverse aide). - .•. �t , : ,.r t :..:x,z,U, Cook Inlet - A prox. 12 miles SW of P -.i �: .o . , rr.:ur •.;l1 E>rr.. M.c2 : ria :� esu OIL } AND GAS CONSERVATION COMMISSION, 5; LEASE DESIGNATION- AND 'SERIAL NO. Alaska 16. DISTANCE FROM PROPOSED•16. LOCATION TO NEAREST 2,0541at T.D. w . S.tate1:: DL l 7 1!,'1 APPLICATION FORI PERMIT TO DRILL, DEEPEN, OR7 PLUG` BACK.:.- :6.-Iia'ilYDIAN,ALLOTTEEO$TBIBENAME la. TYPE OF WORK s _ '. DRIL" L`'°®: DEEPEN ' ❑ PLUG- BACK ❑ t.7. UNIT: AGREEMENT l[ NA&Ai,'1q VIF 3, 5 11 160 750 Sax >rd b. TYPE OF n OIL GAS SINGLE MULTIPLE F]8, FARM OR LEASE °NAME WELL ❑ OTHER ZONE ® ZONE WELL ..... 2. NAME OF OPERATOR . .. Rotary Union=Mobil: State #1 Mobil Oil Corporation 9.," WELL NO. S. ADDRESS OF OPERATOR WORE: WILL START* s'• �3^ 612 S. Flower St.; Los Angeles I7 California '10.- FIELD"ANO POOL, OR WILDCAT 4. LOCATION OF:WELL (Report location clearly and in accorrdance With any -State requirements:•> -Granite' Po1`nt3'Middle Kenai At surface 2361S. & 1258'E. of NW Cor. Sec. 13. At proposed prod, zone (T.D.) 596' S . & 1965'W, of NE Cor. Sec . .14 11.. SEC., T., B., M., OR_BLH. , '- AND'"SURVEY OW AREA -. " Sec. 14, MON, R12W, SM Cook Inlet 14. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE*12. . BAROUGii SH 18. STATE Cook Inlet - A prox. 12 miles SW of P Indian Village of g Z`Y onek Seward meritii.an Alaska 16. DISTANCE FROM PROPOSED•16. LOCATION TO NEAREST 2,0541at T.D. 17-1 2" NO. OF ACRES IN LEASE 17. NO. OF ACRES ASSIGNED TO THIS WELL 2200 PROPERTY OR LEASE LINE, FT. (Also to nearest drlg. unit line; if any) 12-1/411 , 5089 VIF 3, 5 11 160 750 Sax >rd . DISTANCE FROM PROPOSED LOCATION• TO NEAREST WELL, DRILLING, COMPLETED, 3' 100' at 19. PROPOSED .DEPTH 20. ROTARY �OR 'CABLE TOOLS OR "]?I= POR, ON THIS LEASE, Fr. T. D. 9,5701 M.D. Rotary 21. RLEVAnoNS (Show whether DF, RT, GR, etc.) 22.- APPROX. DATE WORE: WILL START* 110' above MLLW datum(KB) I December 15 1966 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT SETTING DEPTH QUANTITY OF CEMENT, 2611 20' 8 6—Q# S.J. 700 1000 Sax 17-1 2" 13-3 8" 6l# 2200 1750 Sax 12-1/411 , 9-5/811 VIF 3, 5 11 9 oo 750 Sax >rd Well will be directed 3674' N 610 18' from surface to 8700' V.D. (anticipated T.D.). Anticipate Middle Kenai at 8185' - 9565' M.D. (7470'-87001 V.D.) . BOP Program: Surface to 24001: 20-3/4" Hydril "MSP", 2000 psi WOG. 2400' T.D.: 13-5/8" Hydril "GK", 5000 psi WOG and 13-5/8" Cameron "U', triple, 5000 psi WOG. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new.productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. ` Give blowout preventer program, if any. 24. I hereby ce i thaw Fob going is True and Correct. slGxm� TITLE Area Superintendent DATE- (This- ATE (This space for Federal or State office use) 1 tZ��GG PERMIT NO. � � APPROVAL DATE THOMAS R. MARSHALL, JR, APPROVED BY � 0 " TITLE Executive Secretary DATE f l CONDITIONS OF APPROVAL, IF ANY: Alaska oil & Gas Conservation Committee P HE *See Instructions On Reverse Side ` N 0 V 21 1966 0�0 --,K/ 10 DIVISION Of MINES & MINERALS 0010-�, i ( i I 34 35 36 31 32 I ,' si0-oo r II PAN -AM Tyonsk St. PAN -AM fi l� 17586 1 � 2 Tyonk St. • fi I 18742 fi I T. ION R. 12 W. dommm.-m-mme Tmolop T.10 N� R. 11 W. i ! 6 32 1 PAN -AM I 5 I I Tyonok St. I I i18742. I . UNION–MOBIL I State No.1 fi 10 it 12 7 i 8 II I PROPOSED LOCATION , ( I +—UNION—MOBIL MOBIL Gronito Pt. I 31 -141965' -ii j �1 MOBIL GRANITE PT. 18765 PLATFORM i X = 283, 353' I fi 15 I,4 I (8 Y= 2,544,555' I fi I I3 17 II I i I ( i l I I fi 22 23 I fi i 24 19 20 I STATE ADL 18761 I PAN -AM HUNT SUPERIOR -TEXACO 18745 17580 21862 MOBIL OIL CORPORATION GRANITE POINT FIELD COOK INLET, ALASKA R E C E I V E D STATE ADL 18761 NOV 21 1966 WELL NO. 31-14 DIVISION OF MINES & MINERALS ANCHORAGE SCALE: I"= 4000' DATE: 10-25-66
