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Home My WebLink About192-150XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. //¢/~"',/~ F ileNumberofWellHistoryFile PAGES TO DELETE · Complete. RESCAN - [] Color items'- Pages: Grayscale, halftones, pictures, graphs, charts- Pages: · . Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA Diskettes, No. Other, No/Type OVERSIZED -~ Logs-of various kinds [] Other COMMENTS: Scanned by: Bevedy Dianna than Lowell TO RE-SCAN Date:/~~ Notes: Re-Scanned by: Be~,edy Dianna Vincent Nathan Lowell Date: Is~ oN OR BEFO W c:t.o~~°c MemOrandum To: Well File: State of Alaska Re: Oil and Gas Conservation Commission Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX API# 029-22801-95 This memo will remain at the from of the subject well file. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to ddll. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remain unchanged. The APl number and in some instances the well name reflect the number of preexisting reddlls and or multilaterals in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddll. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 95. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbering methods described in AOGCC staff memorandum "Multi-lateral (weiibore segment) Drilling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician ARCO Alaska, Inc. Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 July 21, 1994 Ms. Joan Miller Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Well 17-04 Approval Cancellations Dear Ms. Miller: Per our phone conversation of 7/15/94, please cancel the following work Approvals: (1) Permit To Drill- for Rig Sidetracking a new 17-04A wellbore(/~_~"~ (Dated 2/93; Approval # 92-150), and (2) Application Sundry- for the Pre-Sidetrack Plugback of 17-04( wellbore (Dated 1/93; Approval # 92-301). Plans to Sidetrack Well 17-04 have been canceled. A successful Hydraulic Refracture Treatment of the Sag River was performed 2/17/94 as an alternative to the Sidetrack. The well is currently producing at about 800 BOPD, 60% Watercut, & 800 GOR. A Report Sundry for the Fracture Treatment has been filed with AOGCC. Sincerely, Engineering Aide JWP/013 cc. ~. L. Cawvey - (ARCO) - ATO- 1520 ~0Y D. A. Cismoski- (ARCO) - ATO- 1509 ~' M. Sloan- (BPX) - Drilling Dept. RECEIVED JUL 2 5 1994 Alaska 0il & (~as Cons. Commission Anchoraj~ ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA 14EMORA~DU~ ~SlZdk OIL GAS CONSERVATION CO~SSION To ~ Russell A. Doug Date:January 27, 1993 Thru'Leigh Griff in Commissioner Subject' Cement Liner Lap Waiver Prudhoe Bay D~I?-4A %:eli From' 14ichael T Minder $r ?err Engineer T~rry Jordan BP Exploration Design Engineer requested a waiver for the c~ent liner !ap r~quired under 20 AAC 2~.030(5) (B). He Dre~nted data supporting his contention that a Baker model "H" isolation packer provides a positive ~eat on the liner lap and would be adequate for sealing the lap. The lap on this well is located so far above the liner shoe that it is doubtful cement can be pumped high enough to make a good seal. He explained that similar wells k~e-~in the field had been sea!ed by only the packer and passed the prss~ure test. He pointed out. that if the packer did not seal, the lap would fail the pressure test and it could b~ ~que~zed with cement at that time. Terry also said h.e has not encountered any redrills that failed to seal; and attributed it to the Raker mod~! "H" packer. Based primarily on information gathered while drilling the other ¢ide-track~ / redrilI~, and the experience BP has had atte~.~ptin~ to cement extended interval¢,I recomme, nd that the ce~ented lap waiver be granted. I{ it fails under pres~:ure the lap ca~n still he cemented. The best way to address the variance request is to writ.¢ it on the Per, it To Drill for~ 10--401, at the bottom, under '~Conditions of approval, Other." The written response should say "Request for waiver on cemented liner lap grant~d providing a positive :~eal is demor~trated by the pressure $1~te: Alaska ¥¥e!l: DS 1 ?-4A Field: Prudhoe Bay St. Perm_ ~ 92-150 Date 1/12'/93 Engr: M. Minder DS17-4AXL~ Casing inte,~al Interval Size Bottom Top la ? 9175 7162 -2A 0 0 0 SA 0 0 0 4A 0 0 0 5A 0 0 0 6A 0 0 0 ?A 0 0 0 8A 0 0 0 9A 0 0 0 10A 0 0 0 ' Lenglh 3423 0 0 0 0 0 0 0 0 0 Ds ~-'c61Akm D ~-cri¢i~n De,~ Tension Lbs Grade Thread Lbs 26 13CR-80 TBS/FOX 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 IB 2B SB 419 5B 6B 7B 8B 9B lOB Mud Hydrau!io Collapse Wieght Gradient Gradient ppg psi/'ft psilft 9.8 0.510 0.4!0 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 Maximum Minimum Pressure psi 4390 0 0 0 0 0 0 0 0 0 Yield psi BDF 7240 1.6 0 #DIVi0! 0 #DIV!0! 0 #DIVi0! 0 #DiVi0! 0 #DIV~O! 0 #DlVl0! 0 #DIV/0! 0 #DiV/0! 0 #DlVl0! IC 2C 3C 4C 5C 6C 7C 8C 9C 10C Tensiot~ Strength K/Lbs 88.998 0 0 0 0 0 0 0 0 0 Collapse Collapse Pr-Bot-Psi 3768 0 0 0 0 0 0 0 0 Resist. CDF 5410 1.440 0 #glV/0! 0 #DlV/0! 0 #DIVi0! 0 #DIVi0! 0 #DIM/O! 0 #DIVIO! 0 #DiVi0! 0 #DIV/'O! 0 #DIVi0! 7-4ACMT.XLa SI:ate: 'vJeil: r~eld. Si. ate Permit :Ii: Engineer: Work S [neet: Date: M. C~men! Volume Casing Type Casing Size -Inches Casing LenCh- Feel. Hole Diamete~ -inches Cement- Sacks Cement-Yield Cement- Cubic fi. Cement.- Cubic fi. Cement- Sacks Cement- Yield Cemer¢. - Cubic ft Cement.- Cubic It ~12 Cement-Sacks Cement- Yield ~3 Cement- Cubic It ~3 Cement-Cubic ft:!:!:3 Cement- Cubic tt /Vol Cement- FiIi Factor Conductor 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.-5,3,n0 0.000 ~¢DIV/0! Sutbce 0.000 0.000 0.000 O. 000 0,000 0.O00 0.000 0.000 0.000 0.000 0,000 0.000 0.000 0.000 0.000 0.000 ~DIV/0! Linel 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.0O0 0.000 :I:I:DIV/0! Casing Type Casing Size -inches Ca~ing DeCh - Feet. Hole Diamete~-In,es Cement- Sacks Cemenl~ - Yield ~'1 Cement- Cubic irt Cement.-Cubic ft, Cement-Sacks ~12 Cement-Yield Cement- Cubic i~t ~2 Cement- Cubic f~. Cement- Sacks ~.ement- Y~elo ~3 Cement- Cubic Irt Cement- Cubic ft Cement- Cubic ft /Vo! Cement- interval tt Top of Cemeni: - Feet Intermediate .ill 0.000 0.000 0.000 0.P3 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 I.IDtV./O! i~DIV/OI iniermediate 1:I2 0.000 0.000 0. O00 0.~ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~tDIV/0! ~DIV/0! Production 7.000 11,593.000 8.500 0.00 0.00 0.00 238.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 236.00 1,861.10 9,731.9 f,4ea, s,_lred Depth', BP EXPLORATION BP Explora!i~n (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99619-6612 ARCO Alaska, Inc. 'R~~' TELECOPY TO: Name:....~_~ik~" :SATELLITE UNIT Company' Lo~tion: ......... :.. ........ FROM: Name & ExL:rjepartment: :~P~,~,: ~ P;'i"lii-,t~J' ........ PAGES TO FOLLOW (Do not include cover sheet) SECURITY CLASSIFICATION PRIVATE SECRET CONFIDENTIAL ...... ~--~ ......... . ......... i ............... ji .................. '..' .'~" i .... 1 SATELLITE FAX MACHINE FAX# .... 907 564-5193 CONFIRM~ 907 564- Brown Liner Packers A I;tak~r H~ ~ Brown dM Liner }ack Packer !'Product No. 272-25 Rrown IM packer is a tinct-lop ~r that is most frequently run ; .rlrillpipe, using a 'rype C-2 setting Iool [and a liner sleeve with liebaek exten- 'sion. The packer is run ~existing liner tieback extension, and 'than the seal stem is inserted undl .'seated and pressure tested down th, (driltpipe. Additiena~ set-down weight ;shears the release pins i'paC[<er seal. The setting tool is released i~.wl[h right-hand The tieback stem on the Brown JM packer cac~ b, ,:,rd,red whh O. seals for medium-duty service, or with three seu: of gla~s-filied Teflon [chevron seals for more severe pressure A special culler lock nose feature incorporated in the setting shoulder, preventing premature set while running in a deviated hole. The Brown JM tieback packer car.. released by cutting the inside in the designated area. ~rown H Liner Isolation ,roduct No. 28!-02 Brown H packer i~. normally run drillpipe, using a Type C-2 .setting ~ith the liner ~.tttln8 .qle. eve and back extension. The packer is set applyin,~ 2500 psi/17 237 kPa to ddllpipe. To ensure l:ackoff the packer us~s the same upper slips, cone, and packing .ement assemblies as Baker's Modei ,1 ~manen[ packers. Material.s suited for H.~$ service a~)ailab!e on request. -- ~ase pins are aheate0 by setdown selting tee packer seal. lock nose prevents pmmatu-e eot- ling while running in a 4tevie, ted hole.. ;-filled Teflon chevron seals are for severe pressure a.~plications: o. rings ~erve for medium-duty service, Brown JM Liner T~baCk Packer Produc~ No. 272-25 I lrown H Liner Isolation Packer P;o¢~cl No 281-02 )s and cone are the same as thOSe used on / roven ~aker odol F-I permanent packers, ~l~ essured via to 250o 237 kPa to slips. ~7-4A Drilling Permit !nformat, OBJECTIVE: The primary objective of the 17-04 redrill is the return the well to production by drilling a new bottomhole location which is farther upstructure than the current BHL. Openhole logs of the current location indicate the HOT to be just 20' TVD below the top of the Sadlerochit. Moving the BHL farther upstructure should allow a thicker interval of Sadlerochit to be encountered. This well will drain reserves in the southwest area of the 17-10i waterflood pattern. 17-04A will also provide valuable information which will be useful in determining the viability of drilling 17- 17. This well has been shut in for most of its life due to mechanical problems and due to the tar-like emulsion that it produces along with its high watercut (>95%). The data obtained from drilling this well will provide valuable information regarding the viability of location 17-17. The estimated reserves for 17-04A include 400 MBO waterflood reserves, 170 MBO EOR reserves, and 200 MBO Sag reserves, for a total of 770 MBO. The geologic prognosis for this well predicts a net light oil column of 69 feet, which includes an expected 25' of water breakthrough. The estimated initial rates are 1000 BOPD, 50% watercut, and solution GOR. The scope of the 17-4A redrill is to plug and abandon the original perforations, pull the 3-1/2" / 4-1/2" tubing, set a 9-5/8" bridge plug, mill a 60' section in the 9-5/8", lay a cement plug, kickoff and drill a new 8-1/2" hole to a target 1900' northwest of the present wellbore, run open hole logs, run and cement a 7" 26# 13CR/L-80 liner, and recomplete with 4-1/2"/3- 1/2" CR tubing and a 7" CR packer. CURRENT .STATUS: Well 17-4 is currently shut-in due to poor flow potential <100 BOPD at >95% watercut with a black paste-like emulsion that is hindering process equipment. The well was originally drilled and completed in the Sag River in 1980 with the Rowan #35 rig. A 1988 workover changed tubing and added perforation in the Sadlerochit. PERMITTING' A sundry notice covering the plugback of the original well has been submitted. drilling permit covers the proposed drilling program for the redrill. The attached _~_Z-AA Drillina Permit Informati, -- OBJECTIVE' The primary objective of the 17-04 redrill is the return the well to production by drilling a new bottomhole location which is farther upstructure than the current BHL. Openhole logs of the current location indicate the HOT to be just 20' TVD below the top of the Sadlerochit. Moving the BHL farther upstructure should allow a thicker interval of Sadlerochit to be encountered. This well will drain reserves in the southwest area of the 17-10i waterflood pattern. 17-04A will also provide valuable information which will be useful in determining the viability of drilling 17- 17. This well has been shut in for most of its life due to mechanical problems and due to the tar-like emulsion that it produces along with its high watercut (>95%). The data obtained from ddlling this well will provide valuable information regarding the viability of location 17-17. The estimated reserves for 17-04A include 400 MBO waterflood reserves, 170 MBO EOR reserves, and 200 MBO Sag reserves, for a total of 770 MBO. The geologic prognosis for this well predicts a net light oil column of 69 feet, which includes an expected 25' of water breakthrough. The estimated initial rates are 1000 BOPD, 50% watercut, and solution GOR. The scope of the 17-4A redrill is to plug and abandon the original perforations, pull the 3-1/2" / 4-1/2" tubing, set a 9-5/8" bridge plug, mill a 60' section in the 9-5/8", lay a cement plug, kickoff and drill a new 8-1/2" hole to a target 1900' northwest of the present wellbore, run open hole logs, run and cement a 7" 26# 13CR/L-80 liner, and recomplete with 4-1/2" / 3- 1/2" CR tubing and a 7" CR packer. .CURRENT STATU_S' Well 17-4 is currently shut-in due to poor flow potential <100 BOPD at >95% watercut with a black paste-like emulsion that is hindering process equipment. The well was originally drilled and completed in the Sag River in 1980 with the Rowan #35 rig. A 1988 workover changed tubing and added perforation in the Sadlerochit. PERMITTING' A sundry notice covering the plugback of the original well has been submitted. drilling permit covers the proposed ddlling program for the redrill. The attached !7-4A Drilling Permit Inform~ ..~ SU ,M.!VIARY PROCEDURE' . 3. 4. 5. 6. 6a. 7. o , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. Pre-rig work: Kill well. Lay cement plug across perforations to at least 100' above top perforation. Cut 3.5" tubing at ¢.700' MD. Freeze protect. MIRU workover rig. Test intermediate packoff to 3500 psi. Pull BPV. Circulate out freeze protection fluid. Set two-way check valve. ND tree. NU 13-5/8" 5M BOP's. Test BOP's to 5000 psi. Pull two-way check valve. Pull and lay down 4.5"/3.5" tubing. RIH w/9-5/8" bridge plug and set at 8580' MD. RIH with a 9-5/8" section mill and cut a 60' section in the 9-5/8" casing starting at +/- 8320' MD. RIH with open-ended DP. Mix and pump +/-280 sacks of cement to spot balanced kick-off plug from 100' below the base of the section to 750' above the top of the section. 9 5/8" casing is uncemented in this well. Replace intermediate packoff if necessary. RIH with 8,5" Steerable drilling assembly and dress off cement to 5' below section. Kickoff well and directionally drill to align well with target. Drill with a 8.5" packed hole assembly to total depth of 11593" MD / 9105' TVDSS or 150' MD below the OOWC at-9024' s8 TVD. RU wireline and log with the DLL / GR / SP / Sonic. Make wiper trip depending on hole conditions and logging time. Run 7" 26# 13CR FOX x 7" 26# L80 NSCC. standard liner assembly to TD with liner top packer and +/- 150' lap. Crossover from 13CR to L-80 at 10800 MD. Cement liner with 200 sacks based on 40% open hole washout, shoe volume, based on cement fill to 500' MD above Sag River. Clean out liner to PBTD and test to 3500 psi. Test intermediate casing packoff to 3500 psi and replace if necessary. RIH with 3.5" 9,2# 13 Cr 80 FOX/4.5." 12.6# 13 (:;r TDS completion string w/Z" packer. Circulate corrosion inhibitor down the annulus. Space out, land completion, and set packer at 10877' MD based on !50' MD above the too of the Sag river. Test down tubing to 4000 psi. Test tubing x casing annulus to 3500 psi. Set two-way check valve. ND BOP's. NU and test the 4-1/16" 5M tree to 5000 psi with diesel. Pull two way check valve. Shear RP valve and freeze protect. Set BPV. Release rig. ~7..4A Drilli.ng~Perrnit Informali~ SUMMARY P RO_CEDU_BRE.:. , , 3. 4. 5. 6. 6a. 7. , , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. Pre-rig work: Kill well. Lay cement plug across perforations to at least 100' above top perforation. Cut 3.5" tubing at 8700' MD. Freeze protect. MIRU workover rig. Test intermediate packoff to 3500 psi. Pull BPV. Circulate out freeze protection fluid. Set two-way check valve. ND tree. NU 13-5/8" 5M_ BOP's, Test BOP's to 5000 psi. Pull two-way check valve, 4 "/3 5" Pull and laydown ..5 · tubing. 9 " RIH w/9-5/8 bridge plug and set at 8580' MD. RIH with a ~" section mill and cut a 60' section in the 9-5/8" casing starting at +/- 8320' MD. RIH with open-ended DP. Mix and pump +/-280 sacks of cement to spot balanced kick-off plug from 100' below the base of the section to 750' above the top of the section. 9 5/8" casing is uncemented in this well. Replace intermediate packoff if necessary. RIH with 8.5" steerable drilling assembly and dress off cement to 5' below section. Kickoff well and directionally ddll to align well with target. Drill with a 8.5" packed hole assembly to total depth of 11593" MD / 9105' TVDSS or 150' MD below the OOWC at-9024' ss TVD. RU wireline and log with the DLL / GR / SP / Sonic. Make wiper trip depending on hole conditions and logging time. Run 7" 26# 13CR FOX,_x. 7" 26# L80 NSCC standard liner assembly to TD with liner top packer and +/- 150' lap. Crossover from 13CR to L-80 at 10800 MD.. Cement liner with 200 sacks based on 40% open hole washout, shoe volume, based on cement fill to 500' MD above Sag River. Clean out liner to PBTD and test to 3500 psi. Test intermediate casing packoff to 3500 psi and replace if necessary. RIH with 3.~ 9._9,2¢__!3_Cr 80 FOX/4.5" 12.6# 13 Or TDS completion string w/Z" packer. Circulate corrosion inhibitor down the annulus. Space out, land completion, and set packer at 10877' MD based on 150' MD above the top of the Sag river. Test down tubing to 4_.0_0_Q psi. Test tubing x casing annulus to 3500 psi. Set two-way check valve. ND BOP's. NU and test the 4-1/16" 5M tree to 5000 psi with diesel. Pull two way check valve. Shear RP valve and freeze protect. Set BPV, Release rig. 17-4A Drilling Permit Informs,,. ~ PRELIMINARY WELL PLAN WELL: 17-4A Redrill PBU APl No' LOCATION' 50-029-20498-00 (on the original 17-4 well) Surface: 2794' FSL, 4830' FEL, Sec. 22, T10N, R15E Target: 4428' FSL, 2310' FEL, Sec. 28, T10N, R15E @ 8900' ssTVD BHL' 4918' FSL, 2628' FEL, Sec. 28, T10N, R15E @ 9105' ssTVD ESTIMATED START: February 1, 1993 OPP. DAYS TO COMPLETE: CONTRACTOR' Doyon Rig #16 20 (6 days prep & mill, 9 days drill, 5 days complete) DIRECTIONAL: Kickoff at 10,250' MD. 7 degree angle build and 69 degree west turn. WELLBORE: item TVD($s) 20" CONDUCTOR 40' 13-3/8" SHOE 2536' KOP 7190' TOP SAG RIVER SANDSTONE 8798' TOP SADLEROCHIT 8895' TOTAL DEPTH 9105' .MD(BKB) Mud Wt. 110' N/A 2606' N/A 8320' 9.8 11027' 9.8 11205' 9.8 11593' 9.8 LOGGING PROGRAM: 8-1/2" Hole: MUD PROGRAM: Gamma Ray / SP / Laterolog / Sonic The milling/drilling fluid program will consist of a 9.8 ppg XCD polymer / KC! water based mud in the 8-1/2" hole. DEPTH DENSITY PV YP INT 10MIN FL OIL SOLIDS MUD , (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (°./..o)(%) TYPE 7190' 9.8 10 10 5 7 6 0 5 Water to to to to to to to to to Base 9105' 9.8 16 18 10 15 3 0 7 Mud 17-4A Driilino Permit Inform, .,,, MUD WEIGHT CALCULATIONS / WELL CONTROL: Mud Wt. (8-1/2" Hole): 9.8 ppg. Est. Pore Press. Sag River: 4059 psi/8798' ss TVD Est. Pore Press. Sadlerochit: 4103 psi/8895' ss TVD. Overbalance Sag River: Overbalance Top Sadlerochit' 424 psi. 430 psi. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3330 psi based upon a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. LINER DETAILS' CASING DEPTH BURST COLLAPSE TENSILE 7" 26# 13CR80 FOX 10,800' - 11,593' MD 7240 psi (8699'-9105' ss TVD) 5410 psi 604 klbs 7" 26# NT80SS NSCC 8170' - 10,800' MD 7240 psi (7092'-8699' ss TVD) 7" X 9-5/8" Liner Hanger and Liner Top Packer @ 8170' MD 5410 psi 604 klbs CEMENT CALCULATIONS- 7" Liner Measured Depth' 8170' MD (Hanger) - 11,593' MD (Shoe) Basis: 50% open hole excess, 40' shoe joint, and 500' fill above the all oil bearing sands. NOTE; Since cement will not be brought back into the liner lap, the 7" X 9-5/8" 'liner top packer will replace the cement as the mechanical integrity of the liner lap. The liner top packer will help ensure that a pressure seal across the liner lap is achieved. The packer will also allow us to minimize the dg time to cleanout the 7' liner. Total Cement Vol' 236cu ft or 200 sxs of Class G blend @ 1.18 Cu ft/Sk TUBING DETAILS: 4-1/2" 12.6# 13CR-80 TDS 3-1/2" 9.2# 13CR-80 Fox (0'- 8120' MD) (8120' - 11,593' MD,,) ~; ...... ~.~, ~7-~4ADrillinq Permit Informatio PRELIMINARY WELL PLAN WELL: 17~4A Redriil PBU APl No.: 50-029-20498-00 (on the original 17-4 well) .E_OCATION: Surface: 2794' FSL, 4830' FEL, Sec. 22, T10N, R15E Target: 4428' FSL, 2310' FEL, Sec. 28, T10N, R15E @ 8900' ssTVD BHL: 4918' FSL, 2628' FEL, Sec. 28, T10N, R15E @ 9105' ssTVD ESTIMATED START: February 1, 1993 OPR. DAYS TO COMPLETE: 20 (6 days prep & mill, 9 days drill, 5 days complete) CONTRACTOR: Doyon Rig #16 DIRECTIONAL: Kickoff at 10,250' MD. 7 degree angle build and 69 degree west turn. WELLBORE: Item TVD($s) 20" CONDUCTOR 40' 13-3/8" SHOE 2536' KOP 7190' TOP SAG RIVER SANDSTONE 8798' TOP SADLEROCHIT 8895' TOTAL DEPTH 9105' MD(BKB) Mud Wt. 110' N/A 2606' N/A 8320' 9.8 11027' 9.8 11205' 9.8 11593' 9.8 LOGGING PROGRAM' 8-1/2" Hole: .MUD PROGRAM:. Gamma Ray / SP / Laterolog / Sonic The milling/drilling fluid program will consist of a 9.8 ppg XCD polymer / KCI water based mud in the 8-1/2" hole. DEPTH DENSITY PV YP INT 10MIN FL OIL SOLIDS MUD _(T~__D) (PPG) (CP_)_ (~FT) GEL GEL cc/30min (%) (%) TYPE 7190' 9.8 10 10 5 7 6 0 5 Water to to to to to to to to to Base 9105' 9.8 16 18 10 15 3 0 7 Mud 17-4A Drillino. Permit Informs, , DOYON RIG #16 MUD & SOLIDS CONTROL EQUIPMENT _ I_ N _ _ _ _ _ Continental Emsco FA1300 mud pump Brandt shale shaker Alfa-Laval centrifuge Triflow mud cleaner Gas buster Burgess Magna-Vac degasser Sidewinder mud hopper 5 H P agitators Abcor 10 HP agitators 40 bbis trip tank Recording drilling fluid pit level indicator with both visual and audio warning devices at driller's console Drilling fluid flow sensor with readout at driller's console ~L7=4A Driilino Permit Informati(~ _M_UP ~WEIGHT_CALCULATIONS / WELL CONTROL: Mud Wt. (8-1/2" Hole): 9.8 ppg. Est. Pore Press. Sag River: 4059 psi/8798' ss TVD Est. Pore Press. Sadlerochit: 4103 psi/8895' ss TVD. Overbalance Sag River: Overbalance Top Sadlerochit: 424 psi. 430 psi. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3330 psi based upon a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. LINER DETAILS: CASING DEPTH BURST COLLAPSE TENSILE 7" 26# 13CR80 FOX 10,800' - 11,593' MD 7240 psi (8699'-9105' ss TVD) 5410 psi 604 klbs 7" 26# NT80SS NSCC 8170'- 10,800' MD 7240 psi (7092'-8699' ss TVD) 5410 psi 604 klbs 7" X 9-5/8" Liner Hanger and Liner Top Packer @ 8170' MD CEMENT CALCULATIONS: 7" Liner Measured Depth: 8170' MD (Hanger) - 11,593' MD (Shoe) Basis: 50% open hole excess, 40' shoe joint, and 500' fill above the all oil bearing sands. NOTE: Since cement will not be brought back into the liner lap, the 7" X 9-5/8" liner top packer will replace the cement as the mechanical integrity of the liner lap. The liner top packer will help ensure that a pressure seal across the liner lap is achieved. The packer will also allow us to minimize the rig time to cleanout the 7" liner. Total Cement Vol: 236cu ft or 200 sxs of Class G blend @ 1.18 Cu ft/Sk TUBING DETAILS: 4-1/2" 12.6# 13CR-80 TDS 3-1/2" 9.2# 13CR-80 Fox (0'- 8120' MD) (8120'- 11,593' MD) '~_7~-4A Drilling Permit Informatio. DOYON RIG #16 ~IUD & SOLIDS CONTROL EQUIPMENT Iw _ _ m w _ _ _ _ Continental Emsco FA1300 mud pump Brandt shale shaker Alfa-Laval centrifuge Triflow mud cleaner Gas buster Burgess Magna-Vac degasser Sidewinder mud hopper 5 HP agitators Abcor 10 H P agitators 40 bbls trip tank Recording drilling fluid pit level indicator with both visual and audio warning devices at driller's console Drilling fluid flow sensor with readout at driller's console ALASKA OIL AND GAS CONSERVATION COM~IISSION February 5, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 2767542 Michael Zanghi, Drlg Engr Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 17-4A ARCO Alaska, Inc. Permit No. 90~-150 Sur. Loc. 2486'FNL, 450'FWL, Section 22, T10N, R15E, UM Btmnhole Loc. 4918'FSL, 2628'FEL, Section 28, T10N, R15E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to redrill the above referenced well. The requirement to have a minimum of 100 feet of cemented (liner) lap within the next larger casing [20 AAC 25.030(d)(5)(B)] ks hereby waived. This waiver is predicated on placement of liner isolation packer and demonstration of positive seal by pressure test. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ODER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ p,inted on recycled pape, b y STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] RedrilllTIIlb. Type of well. Exploratory[] Stratigraphic Testr-I Development OilE] Re-Entry [] DeepenI-II Service [] Development Gas [] SingleZone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KB = 70feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. 0. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28331 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2486' FNL, 450' F1/VL, Section 22, TION, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well number Number 4428' FSL, 2310' FEL, Section 28, TION, R15E, UM DS 17-4 A U-630610 At total depth 9. Approximate spud date Amount 4918' FSL, 2628' FEI_, Section 28, TION, R15E, UM February 2, 1993 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line 362 feet No Close Approachs feet 2560 11593' MD / 9175' TVD~eet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~o2sofeet Maximum hole anglesz.~° Maximum surface 3330psig At total depth (TVD) 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# ~3cr-ao/ Fox/ 3423' 8170' 7162'i 11593' ~9175' 236 cu ft Cl 'G' NT-BO$$ NSCC RECE[ 119. To be completed for Redrill, Re-entry, and Deepen Operations. DEC ~ ?- 199~ Present well condition summary Total depth: measured 11955 feet Plugs (measured) .Alaska 0il & Gas Cons. true vertical 9653 feet Anchorage Effective depth: measured 11910feet Junk (measured) true vertical 9618feet Casing Length Size Cemented Measured depth True Vertical depth Structural Co nd ucto r 80' 20" 390 sx ASI/ 110' 110' Surface 2567' 13-3/8" ~97ssxr-~u~=P/=~ 2606' 2606' Intermediate 10644' 9-5/8" 800sxCI'G'&3OOsxPFC 10680' 8685' Production Liner 1528' 7" 550 sx Cl 'G' 10360'-11950' 8474'-9650' Perforation depth: measured 11019'-11043', 11140'-11160' true vertical 8934'-8958', 9029'-9044' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify ~,/at the foregoing! is true and correct to the best of my knowledge Signed(f - ..~~.,. ~ Title Drilling Engineer Supervisor ~- Date Commission Use Only Permit Number IAPI number IApproval d~te ISee cover letter ¢~-/...<-c:, 15o-o.z<~- :z-oz-/9'o~-o) I ~ ~.~T~---~'~ Ifor other requirements Conditions of approval Samples req_uired [] Yes fl~I'NO Mud Icg requir.ed [] Yes ,~'No Hydrogen sulfide measures [] Yes J~ No Directional survey requ~rea ,,2g Yes [] No Required working pressure for BOPE 1-12M; 1-13M; ¢5M; 1-110M; []15M; Other: by order of e~ ~:--~ed '~" Commissioner me commission Dat Approved by Origina! .z-:.,.~...,, ,~,,+,-,~ ........ Form 10-401 R ,e~e.d~'~-1V85d'-u~i";$ Submit in triplicate ~-'". STATE OF ALASKA ' AL .KA OIL AND GAS CONSERVATION COMMIS;_._,N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon,.x Suspend ~ Operation Shutdown . Re-enter suspended well__ Alter casing ~ Repair well ~ Plugging x 'Time extension ~ Stimulate Change approved program .. Pull tubing ~ Variance__ Perforate ~ Other x Plugback for Redrill 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska,/nc. Development x KB = 70 feet Exploratory 3. Address StratJgraphic__ 7. Unit or Property name P. 0. Box 196612, Anchorage, Alaska 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2486'FN1., 450' FWL, Section22, TION, R15E, UM DS 17-4 At top of productive interval 9. Permit number 1753' FNL, 1040' FEI., Section 28, TION, R15E, UM 80-85 ,., At effective depth 10. APl number 2176' FNL, 1351'FE!.., Section 28, TION, R15E, UM 50- 029-20498 At total depth 11. Field/Pool 2176' FNL, 1351' FEI., Section 28, TION, R15E, UM Prudhoe Bay Field/Oil Pool 12.' Present well condition summary Total depth: measured 11955 feet Plugs (measured) true vertical 9653 feet Effective depth: measured 11910 feet Junk (measured) _. true vertical 9618 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 20" 390 sx ASII 110' 110' Surface 2567' 13-3/8" 1975 sx Fondu & 400 sx PFII 2606' 2606' Intermediate 10644' 9-5/8" 800 $xCI 'G" & 3OO sx PF C 10680' 8685' Production Liner 1528' 7" 550 sx Ci ~' 10360'-11950' 8474,9650' Perforation depth: measured11019-1104,3',11140,11160' R E C E IV E D true vertical 8934'-8958', 9029'-9044' DEC _? 2 1992 Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 @ 10409' ~,laska 0ii & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 9-5/8"Baker 'SAB' pkr @ 10321 ? 3-1/2" Camco 'TRDP' SSSV @ 2211' 13. Attachments Description summary of proposal x Detailed operations program ~ BOP sketch x 14. Estimated date for commencing operation 15. Status of well classification as: February 1, 1993 16. If proposal was verbally approved Oil x Gas ~ Suspended ~ Name of approver Date approved Service 17. I hereby c( rtify that~he foregoing is true and correct to the best of my knowled~le. / .,.'? I .Signed ~1- "~---~!. Title Drilling Engineer Supervisor Date fZ..- FOR COMMISSION USE ONLY Conditio'ns of approval: Notify Commission so representative may witness ,lu -X- T.st L a io. o ea, .c.II*¢,,ow Mechanical Integ~lO- ~tg? Approved by order of the Comm Commissioner Date //~//~ ~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE SUBJECT / ~ '" q A ENGINEERING DATA SHEET NO.~ OF.__ BASED ON ENGINEER ~/~ t~-~PT. APP'VL DATE BUDGET/AFE NO. , ~ ~/~ ~ ~,~ ~o. t! · . :: : . ; i .! :-' ': ~:'.i i." i~;'''.~:~:~v,'? .: ,. ~.D'. .... ~......i ...... ~: ' - ......................... - ................ _ ................................... ~ ................. .....~ii .................. Alasl{~ Oil 8, Gas Co~s. Cormnission . ....... i ............................................... - .................. :: ' Anchora~lo .................... : ............. .'i ................................... i:. '7".. ~ tl ~¢3 ~-a/. ,t/os~, i - ............ ; ................ ..................................... .......... ............ : ................................. :~....~ ............. i ....... . .. '.. ' .... AK 23574 (6186) '-4A Drilling Permit Inf0r t~ DOYON RIG #16 MUD & SOLIDS CONTROL EQUIPMENT _ w _ u _ a m _ _ Continental Emsco FA1300 mud pump Brandt shale shaker Alfa-Laval centrifuge Triflow mud cleaner Gas buster Burgess Magna-Vac degasser Sidewinder mud hopper 5 H P agitators Abcor 10 HP agitators 40 bbls trip tank Recording drilling fluid pit level indicator with both visual and audio warning devices at driller's console Drilling fluid flow sensor with readout at driller's console /~laska. 0JJ & Gas C0;'l$. Oori~rr~issio~ Anchorage : DEC-15-1992 15:53 FROH GREAT LAND DIR DRILLING TO F'BD EI'..kGINEER'=_, P.02 GREAT LAND DIRECTIONAL DRILLING, INC. Corporate O~ice 1111 East 80th Avenue R CEIVEB (907) 349-4511 Fax 349-2485 ,Alaska O~l & nas Co,is. /~¢horago DIRECTIONAl. ~LL PL~ for PRUDHOE BAY DRIVING well ......... Field ........ : Prudhoe Bay Drill Site 17 Computation..: MINIMUM CURVATURE Prepared ..... : 12/15/92 Section at...: 268.35 KB elevation.: 70.00 LEGAL DESCRIPTION Surface ...... : 2794 FSL 4830 FEL S22 T10N R15E UM Tie-in ....... : 241 FSL 223 P~L 82~ Ti0N R15~ UM Target ....... : 4428 FSL 2310 FEL S28 TiON R15E %TM BHL .......... : 4918 FSL 2628 PRL $28 T10N ~i5~ UM X ASP ZONE 4 Y 708702.87 5928143.23 708105.49 5925573.44 706037.00 5924924.00 705719.71 5924905.23 PROPOSED WELL ~ROFIL~ STATION IDENTIFICATION TIE-IN K-10 F~AS INCLN DEPTH A/{GLE VERT-DEPTHS SECT BKB SUB-S DIST 8320 49.85 7260 7190 741 198.80 8400 49.04 7312 7242 764 202.88 8424 48.85 7327 7257 772 204.10 8500 48.23 737~ 7308 798 208.10 8600 47.66 7445 7375 838 213.43 DIRECTION REL-COORDINATES AZIMUTH FROM-WELL~L%AD DLI !00 2551 S 668 W <TiE 2608 $ 690 W 4.0 2625 S 697 W 2676 S 722 W 4.0 2740 S 760 W 4.0 8700 47.35 7512 7442 883 218.84 8800 47.29 75@0 75!0 934 224.28 8900 47.49 7648 7578 989 229.71 9000 47.94 7715 7645 1049 235.08 9100 48.64 7782 7712 1~i3 240.36 2799 2854 2904 2949 2989 803 W 4.0 852 W 4.0 906 W 4.0 964 W 4.0 1027 W 4.0 END OF CURVE K-5 LCU/K!NG~2K SAG RIV]~R SHUBLIK 9200 49.57 7847 7777 1181 245.51 9300 ~0.73 7911 7841 1253 250.50 9400 52.09 7974 7904 1328 255.31 9500 83.64 8034 7964 1407 259.93 9600 55.36 8092 8022 1~B8 264.37 9694 57.1i'' 8144 8074 1565 268.35 9697 57.11 8146 8076 1568 268.35 10708 ~7.11 8695 8~25 2417 268.35 11027 57.11 8868 8798 2685 268.35 11071 57.11 8892 8822 2722 268.35 3024 3052 3075 3092 3103 3108 3108 3133 3140 3142 1095 W 4.0 1166 W 4.0 1241 w 4.0 1318 W 4.0 1399 w 4.0 1477 W 4.0 1480 W 0.0 2328 W 0.0 2596 W 0.0 2633 W 0.0 TOP SADLEROCBIT ZONE 4/48 TARGET POWC OOWC ZONE 4A/X-PJiY TD 11205 57.11 8965 8895 2835 268.35 11205 57.11 8965 8895 2R35 268.35 11215 57.11 8970 8900 2843 268.35 -11343 57.11 9040 8970 2951 268.35 11443 57.11 9094 9024 3034 268.35 11448 57.11 9097 9027 3039 268.35 11593 57.11 9175 9105 3160 268.35 3145 3145 3145 3148 3151 3151 3154 2746 W O. 0 2746 W 0.0 2753 W 0.0 2862 W O. 0 2945 W 0.0 2950 W 0.0 3071 W 0.0 (GLDD (c)92 D-~I?'4A BI.36 _~:12 PM 2) GP~AT LAND DIRECTIONAL DRILLING, iNC. Corporate O:fice 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PL~ for PRUDHOE BAY DRILLING Alaska 0it ~ ~,S C;Oils. (Jommissio[ A.~rhora o well ......... : DS 17-4A (P3) . Field ........ : Prudhoe Bay Drill Site 17 Computation..: MINIMUM CURVATURE LEGAL DESCRIPTION Surface ...... : 2794 FSL 4830 FEL S22 T10N R15E UM Tie-in ....... : 241FSL 223 PEL 521T10N R15E UM Target ....... : 4428 FSL 2310 FEL S28 T10N R15E UM BHL .......... : 4918 FSL 2628 PEL $28 T10N Ri5E UM Prepared ..... : 12/15/92 Section at...: 268.35 KB elevation.: 70.00 X ASP ZONE 4 Y 708702.87 5928143.23 708105.49 5925573.44 706037.00 5924924.00 705719.71 5924905.23 PROPOSED WELL PROFILE STATION IDENTIFICATION TIE-IN K-10 F~AS INCLN DEPTH ~{GLE 8320 49.85 8400 49.04 8424 48.85 8500 48.23 8600 47.66 VERT-DEPTHS SECT BKB SUB-S DIST 7260 7!90 741 7312 7242 764 7327 7257 772 7378 7308 798 7445 7375 838 DIRECTION REL-COORDINATES DL/ AZIMUTH PROM-WELL~D !00 198.80 2551 S 668 W <TiE 202.88 2608 S 690 W 4.0 204.10 2625 S 697 W 4.0 208.10 2676 S 722 W 4.0 213.43 2740 S 760 W 4.0 8700 47.35 8800 47.29 8900 47.49 9000 47.94 9100 48.64 7512 7442 @83 7580 75!0 934 7648 7578 989 7715 7645 1049 7782 7712 1113 218.84 2799 S 803 W 4.0 224.28 2854 E E52 W 4.0 229.71 2904 S 906 W 4.0 235.08 2949 g 964 W 4.0 240.36 2989 S 1027 W 4.0 E.~ OF cu~vE K-5 LCU/KING~_'~ SAG RIVE-R SHUBLIK TOP S~_DLEROC~I T ZOnE 4/~ TARGET POWC OOWC ZONE 4A/X-RAY TD 9200 49.57 9300 50.73 9400 52.09 9500 53.64 9600 55.36 9694 57.1i' 9697 57.11 10708 57.11 11027 57.11 11071 57.11 11205 57.11 11205 57.11 11215 57.11 -11343 57.11 11443 57.11 11448 57.11 11593 57,il 7847 7777 1181 7911 7841 1253 7974 7904 1328 8034 7964 1407 8092 8022 1~88 8144 8074 1565 8146 8076 1568 8695 8625 2417 8868 8798 2685 8892 8822 2722 8965 8895 2835 8965 8895 2R35 8970 8900 2843 9040 8970 2951 9094 9024 3034 9097 9027 3039 9175 9!05 3160 245.51 3024 S 1095 W 4.0 250.50 3052 S 1166 W 4.0 255.31 3075 $ 1241 W 4.0 259.93 3092 g 1318 W 4.0 264.37 3103 S 1399 W 4.0 268.35 3108 S 1477 W 4.0 268.35 3108 S 1480 W 0.0 268.35 3133 S 2328 W 0.0 268.35 3140 S 2596 W 0.0 268.35 3142 S 2633 W 0.0 268.35 3145 E 2746 W 0.0 268.35 3145 $ 2746 W 0.0 26S.35 3145 S 2753 W 0.0 268.35 314S S 2862 W 0.0 268.35 3151 S 2945 W 0.0 26S.35 3151 S 2950 W 0.0 268.35 3154 S 3071 W 0.0 :GLDD (c)92 DSl?4A B1.36 3:12 Warkar Identification MD BK8 SEClN INCLN A] IIEIIN 8320 7~60 741 4~,8§ B) END OF CURVE 9694 8~4~ J565 57.~J C) TARGET i~2i5 B970 2843 5?.JJ D) TD JJ593 gi75 3160 57.JJ ........................... PRUDHOE BAY DR ILL I NG DS 17-4A (P3) VERTICAL SECTION VIEW Section at: TVO Scale.: Oep Scale.: Dpa~n ..... : 268.35",~.~ ~"" '~"~ ~ J 1 inch - 400 feet 12/J5/92 DEr. Great Land OJrectioh~°~'lYp) ]ling 400 §00 BOO tO00 .. ~400 ~lBO0 :1800 SBction OepsPtupe 2000 2~00 8400 8600 2800 3000 3800 ! -PRU-DHOE BAY DRILLT. NG 40O VERTICAL SECT VIEW C ElY E b TVD Scale.' 1 ~ncn = 4oo feet u =i= ii~ i ~i ,t !: ~ '~i ~ I Drawn ..... : 12/J5/92 ~[askaOJJ&GasCons. ;~lii ;; i i: :l l, I , i [ Cornmis~, . , --,--!--+'--HI---~-I I , .... i -_ Anchoraq~ u "* TM 'f ''?~ "f"'r'-f' -z.4.4.. [ ' 3 ~ ~ ~ ' ' ' · ,--:'47-'M'-=~"~'='t"~","l-~ .... ~'=q-T'r--~l'"-H+-~-Hi ~, ~/~,/~,. ~ i, , ~ - '~- --~ ..... ' .... %-~ .... f 'l'fl ...... ~"'~' ~--~ ..... " · ~, , ~ ,' t. fl .' h , .,,~ ."'" /,, . ,~ , , ~,_= ..... ~_!..]. ":' ~-~'' .:.-~ . I....;....,r~ . . _ i{l ..... 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",.. 600 Boo tooo 1200 t400 J600 t800 2000 2a00 2400 2600 2800 3000 3800 Sect ~.on Depanture karker Identit icatior, Al TIE-IN B) EN8 DF CURVE C) TARGET D) TD MD BKB SECTN INCLN 8320 7260 741 49.85 9694 8]44 t~ 57.ii t~2t5 8970 2843 57.i] J~593 9t75 3160 57.1J Oep Scale.' J inch --' 400 ~, 2 2 1992 ., ]-)EC:-i~-iQ'q.---'.~ _._._ 15:==,.;,¢ FROH CF.:EH I _l AI-4D DIP.' .LJP-.:iLLiHL~ I~_ ~ N/s E/~ Marker Identification A) TIE-IN B) ENO OF CURVE C) TARBET D) TD 31OB 1477 3154 ~307i ~ DEC t 'Z ~oo~, Alask~. Oil & Gas Cons. Anchorage DS 17-4A (P3) PLAN VIEW CLOSURE ..... : 4402 ft at Azlmuth 224.23 DECLINATION.: 30.23 E SCALE ....... : ~ inch = 600 feet :DRAWN ....... : ]2/~5/§2 Srea t L and Oirec t i ora] Drj l lJng ? 3900 3600 3300 3000 2700 2400 2100 1800 mi mi 1500 ;200 900 600 3OO 0 3OO <- WEST · EAST -> TOTAL P. 04 PRUDHOE BAY DRi-L-LING Narker IOentifiCation A] TIE-IN B) ENK) OF CL~qVE £) IARGET O) TD ,_ ~0 ~4/S E/~' 8320 2551 SSS 66B ~ 9694 3~08 !477 J~2J5 31~5 2753 2593 3154 S 307~ ,-', ~ , Alaska Oil ~ c~as Cons. AnchoraGe DS 7-4A (P3) PLAN VIEN CLOSURE ..... : 4402 ft at Azimuth 224.23 DECLINATION.: 30.23 E SCALE ....... : J inch = 600 feet DRAWN ....... : ~2/J5/92 Great Land Directional Drilling _ 3900 3600 3300 3000 2700 2ZOO 2100 1800 ~500 1200 mi §00 60O I 300 0 300 <- WEST' EAST-> ,, TOTAL P.04 DOYON 16 13 5/8'' 5,000 psi Stack 10.15 4.5 5.02 r ,- RKBI RI( ~ FLO ! I HYDRIL 12.40 Variable 3.5" x 6" Pipe Ram 15.40 17.60 GROUND LEVEL .02 1.80 2.35 0.25 Variable 4.5" x 7L" Pipe Ram MUD CROSS Blind Ram TBG SPOOL TBG SPOOL BASE FLG 20.70 I24.85 25.10 .Alaska,. Oil & Gas Cons. (;orn~ission Anchorage DOYON 16 13 5/8" 5,000 psi Stack 10.15 4.5 F RKB 1 5.02 1.02 1.80 2.35 0.25 I HYDRIL RI( ~FLO Variable 3.5" x 6" Pipe Ram Variable 4.5" x 7L" Pipe Ram 12.40 l' I 15.40 MUD CROSS GROUND LEVEL R . 17.60 Blind Ram TBG SPOOL TBG SPOOL BASE FLG 24.85 20.70 25.10 Alaska 0il & Gas Cons. Anchorage ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE ( 2 ) Loc /~/0~ [2 thru [14 thru 22] [23 thru 28] rev 12/92 jo/6.011 Company YES 1. Is permit fee attached ............................................... .X 2. Is well to be located in a defined pool .............................. ~ 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... ~ 5. Is sufficient undedicated acreage available in this pool ............. i~. 6. Is well to be deviated $ is wellbore plat included ................... ~ 7. Is operator the only affected party ................................... /~ 8 Can permit be approved before 15-day wait ............................ . 10. 11. 12. 13 14 15. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... DoesIS leasewell ntrnberhave aappr°priateunique name ......................................... ~ number Is conductor string provided . Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface g intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ ~s drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of dj-::'_ _~3-.~BOPE at:ached .... Does BOPE have sufficient pressure rating -- %est to ~~:x psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... Lease .& Well ~ ~~ NO 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. REMARKS 29. 30. 31. 32. FOR EXPLOP~ATORY & STRATIGRAPHIC WELLS: Are data presented on poten%ia] overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results o~ seabed conditions presented... Name and phone nLrnber of con~act to supply weekly progress data ...... 33, Additional requiremen%s ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE HERID~AN' remarks' UMX SM TYPE' Exp/Dev ~ Redril I ~ Inj Rev