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198-057
Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~'.~'-~"~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: n Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds n Other COMMENTS: Scanned by~r~ Damth;-/Nath.#n Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha(Nathan ~.owell Date: Is' ALASKA OIL AND GAS CONSERVATION CO~IISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 R. Marty Lemon Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 September 6, 2001 Re: Cancelled or Expired PTD's. Dear Lemon: The Alaska Oil and Gas Conservation Commission ("AOGCC") approved the following referenced permit to drills. The AOGCC has a long-standing policy of releasing cancelled or expired permits two years from the date the application was approved by the AOGCC. The following files are scheduled to be released October 1,2001. Permit to Drill No.'s: 97-161 98-027 98-057 98-073 99-013 Sincerely, Executive Secretary Memorandum To: Well File: State of Alaska Oil and Gas Conservation Co~ Cancelled or Expired Permit Action EXAMPLE: Point Mclntyre P2-36AXX API# 029-22801-95 This memo will remain at the from of the subject well f'de. 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 i' the treatment of these kinds of applications for permit to ddil. 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 remair unchanged. The APl number and in some instances the well name reflect the number of preexistin! reddlis ancl or muitilaterais in a well. In order to prevent confusing a cancelled or expired permit an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddil. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 9~, The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the AP! numbering methods described in AOGCC staff memorandum "Multi-lateral (welibore 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 October 26, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Cancellation of Approved Permit to Drill for 1C-17 Dear Mr. Commissioner: This is to inform you of our intentions to cancel the approved Permit to Drill for the 1C-17 Kuparuk well in the Kupamk River Unit. The permit number is 98-57, API #50-029-22872. Sincerely, G. L. Alvord Kupamk Drilling Team Leader Kuparuk Development GLA/skad Oli& ~as {;ohS. ~ TONY' KNOWLE$, GOVERNOR · ALAS~ OIL ~ GAS CONSERVATION CO~IISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: i907) 276-7542 April 6. 1998 Mike Zanghi Drilling Superintendent ARCO Alaska. Inc. PO Box 100360 Anchorage, AK 99510-0360 acz Kupamk Rivcr Unit 1 C- 17 ARCO Alaska. Inc. Permit No 98-57 Sur. Loc.: 1395'FNL. ~63'FWL. SEC. 12. TI IN. RIOE. UM Btmholc Loc: 458'FNL. 1938'FWL. SEC. 02. TI IN. RIOE. UM Dear Mr. Zanghi: Enclosed is thc approved application for permit to drill thc above referenced xvcll. This approval includcs annular disposal of drilling xvastcs and is contingent on obtaining a well ccmcnted surface casing confirmcd by a valid Formation Integrity Tcst (FIT) - cementing records. FIT data. and an',' CQLs arc to bc submittcd to thc Commission prior to thc state of disposal operations. The permit to drill docs not exempt you from obtaining additional permits rcquircd by lax,,' from other governmental agencies, and does not authorize conducting drilling opcrations until all other required permitting determinations arc made. Bloxvout prcvcntion cquipmcnt (BOPE) must be tcstcd in accordancc xx'ith 20 AAC ":'.035. Sufficicnt noticc (approximatcly 24 hours) of the BOPE test pcrtbrmcd before drilling below thc surface casing shoc must bc givcn so that a rcprcscntativc of thc Commission may ~vitncss thc test. Notice may be given by contacting the Commission pctrolcum field inspector on thc North Slope pager at 659-3607. David W. Jolm.ston '~ ~ Chairman ""-~_ BY ORDER OF THE COMMISSION ,ill-/enclosures l)epartment of Fish & (;amc. I labitat Section w o cncl. l)cparlment of |:.nvironmcn! Conservation w o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 : la. Type of Work Drill X Redrill -- i lb. Type of Well Exploratory__ Stratigraphic Test __ Development Oil _ Re-Entry__ Deepen __ i Service X Development Gas__ Single Zone X Multiple Zone 2. Name of Operator i 5.Datum Elevation (DF or KB) ! 10. Field and Pool ARCO Alaska, Inc. J RKB 29', Pad 61' :. Kuparuk River Field 3. Address i 6. Property Designation i Kuparuk Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 !~ ADL 25649 ALK 467 , 4. Location of well at surface i 7. Unit or property Name i 11. Type Bond (see 20 AAC 25.025) 1395' FNL, 563' FWL, Sec. 12, T11N, R10E, UM ~ Kuparuk River Unit ~ Statewide · At top of productive interval i 8. Well number i Number ~ i 531' FNL, 1982' FWL, Sec. 2, T11N, R10E, UM i 1C-17 i #U630610 At total depth i 9. Approximate spud date Amount i 458' FNL, 1938' FWL, Sec. 2, T11N, R10E, UM i 4~6~98 , i $200,000 12. Distance to nearest ! 13. Distance to nearest well i 14. Number of acres in property '. 15. Proposed depth (MD and TVD) property line i 1C-09 ! ~, MD 10,400' 531' feet - 20' at 462' MD feet ! 2560 I TVD 6,690' feet ; 16. To be completed for deviated wells i 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) I kickoff depth 250 feet Maximum hole angle 58° i Maximum surface 3190 psig At total depth (TVD) 3900 psig I 18. Casing program i ,, Setting Depth i size ~ Specification I Top Bottom ', Quantity of cement Hole i Casing i Weight i Grade I Coupling ~ Length~ MD i TVDI MD t TVD i (include stage data) ~ I 108' i 108' i Permafrost Cement 20" i 16" i 621bi B I We~d ! 80' i 28' ~ 28'~ 12-1/4"i 9-5/8" i 40lb I L-80 I BTC i 6932'i 28' i 28' i 6960'i 4324' ', +/- 900 sx AS3L, 600sxG 8-1/2" ! 7" ! 26 lb i L-80 I BTC i 10022'i 28' i 28' ! 10,050'i 6356' i +/_ 100 sx G 6-1/8" i 4-1/2" i 12.61bi L-80 I NSCT i 550' i 9850' ~! 6179' i 10,400'I 6690' ] +/- 50sxG 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth Tr~ ,r~a~lp~, I- I~ Structural Conductor Surface Intermediate M~19 1998 Production Liner Perforation depth: measured A~ka 0il & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee ~ Property plat__ BOP Sketch ~ Diverter Sketch x_. Drilling program x.z- Drilling fluid program ~x Time vs depth plot__ Refraction analysis Seabed report __20 AAC 25.050 requirements Z1. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~-~{2 ~"~~ ,~'3~ .,?.~,z-~ Title Drilling Superintendent Date · vi Commission Use Only Permj.t..N_umber i APl number ' Approval date li,jljC.~r.j i See cover letter for ~;~'-,-~"7 i 50- ~:3 ~_. 9-" ~--'~' <~' ~'.~---_'~e~s ~.~' i other requirements Conditions of approval Sampies required _Yes ~'No Mud log required No Hydrogen sulfide measures ,~-'Yes _ No Directional survey required,~'Yes _ No Required working pressure for BOPE _ 2M; _ 3M; '~5M; _ 10M; _ 15M Other: David W, Johnston by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 . u t in triplicate GENERAL DRILL AND COMPLETE PROCEDURE KUPARUK RIVER FIELD - INJECTOR KRU 1C-17 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 12.25" hole to 9-5/8" surface casing point (+/6960' MD) according to directional plan. 4. Run and cement 9-5/8" casing, using stage collar placed at least 200' -I-VD below the base of the permafrost, and light weight lead cement. 5. Install and test BOPE to~si. Test casing to 2000 psi. 6. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 7. Drill 8.5" hole to intermediate TD (+/- 10,050') according to directional plan. 8. Run and cement 7" intermediate casing string. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. 9. NU and test BOPE to 5000 psi. Test casing to 3500 psi. ~ 10. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 11. Drill 6.125" hole to well total depth (+/- 10,400') according to directional plan, running LWD logging equipment as needed. 12. Run and cement 4-1/2" NSCT liner with Baker liner-top packer and hanger. Hydraulically set packer +200' inside intermediate casing shoe to provide appropriate liner lap. 13. Pressure test liner to 3500 psi. 14. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. 15. ND BOPE and install production tree. 16. Shut in and secure well. 17. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. Note: As a dedicated injector, cased hole cement bond logs (SLT-J or CBT) will be run to establish isolation after the cleanout is completed, but prior to perforating. 19 !998 Alaska 0il & Gas Cons. Commission Anchorage 1 C-17 FJ,03/18/98, v.1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Well KRU 1C-17 Drillincl Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.5-10.2 15-35 25-50 130-150* 10-25 15-40 5-7 9.5-10 +10% Drill out to 7" interm, casing 8.8-9.0 4-8 5-8 35-4O 2-4 4-8 8-15 9.5-10 4-7% Drilling Fluid System: Drill out to TD 11.5-12.5 15-25 5-8 50-65 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Triple Derrick Shale Shakers Desander, Desiter, Mud Cleaner Centrifuge Degasser RECEIVFD Pit Level Indicator (Visual and Audio Alarm) '~ Trip Tank Fluid Flow Sensor ~.~.;~ ~ 9 199 Fluid Agitators *Spud mud should be adjusted to a FV between 130-150 sec/qt to drill gravel beA~ska 0JJ & Gas Cons. Commissiorl Anchorage Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure while drilling the 8-1/2" intermediate hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0,11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2,672 psi. Therefore ARCO will test the BOP equipment to 3000 psi after setting surface casing. MASP = (4324 ft)(0.70- 0.11) - 2551 psi Maximum anticipated surface pressure while drilling the 6-1/8" hole below intermediate casing is calculated by subtracting a gas gradient of 0.11 psilft from the bottom hole reservoir pressure of 3900 psi. This shows that the maximum surface pressure would be 3190 psi. Therefore, ARCO will test of the BOP equipment to 5000 psi after setting the intermediate casing. MASP = 3900 psi - (6456' x.11 psi/fi) - 3190 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of 1C pad are expected to be 3900 psi (0.60 psi/fi). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 12.0 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 6456'. Well Proximity Risks: The nearest existing well to 1C-17 is 1C-09. As designed, the minimum distance between the two wells would be 20' at 462' MD. Drillin_~ Area Risks: Risks in the 1C-17 drilling area include lost circulation and high pressures in the Kuparuk formation. Both are addressed by setting intermediate casing above the Kuparuk. Careful analysis of pressure data from offset wells shows that a mud weight of '12.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" and 7" casing shoes will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of well 1C-'12 or another permitted existing well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The lC-17 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 1C-17 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDVV's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoes will be set +200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 4325 psi The pressure is very conservative as frictional losses while pumping are not accounted for. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (lb/fi) Grade Range Type (psi) Collapse (psi) Burst 9.625 40 L-80 3 BTC 3090 2627 5750 4888 7.000 26 L-80 3 BTC-M 5410 4599 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 ~ (1). 1 C-17 F J, 3/18/1998, v. 1 !Crea,,¢ oy :inc~ For: F JOHNSON ~la! ~e~er~nce ~o ~ 7 V~s;on ~2. Cc~r~flotes crc fl ~e~ re~e~ce ~ f17. 500 ~ 1000 ~ ~ SO0 ~ 2000 ~ 2500 ~ 3C00 ~ 3500 4000 4500 6000 ARCO Alaska, Inc. Structure : Pad 1C Well : 17 Field : Kuporuk River Unit Location : North Slope, Alaska <- West (feet) 4000 3500 3000 2500 2000 1500 1000 500 TO LOCATION: , .~l ~ ~ i I : , ~ i i ~ i i , i , ~ i 6500 458' FNL, 1938' FWL I / _~ "xTD - Casing Pt . . J SEC. 2, T11N, RIOE J [ ,A.'~. ITarget - Top C4(EOO) k ,\/Bose H~Z T~c~ ~OCAT,O~: , ~oo ~ C35 c~ C50~ TARG~ 550C ~ ~0=6456 ', ~ TMO=DEP=725710 ~8egin Angle 0rap / 327.85 AZIMUTH ~ NORTH 6144 WEST 38~ k ~000 *~.P!one of Proposal*** CBO~Companian SS 4500 Cl00~g 5/8 Casing 0 F a0CC RXB ELEVAT~CN: 89' ~ }500 Wes[ Sok Sands L ~KOP T~=250 TAD=250 DEP=0 ~ 4.oo ~9'1513'29BEGiN ~UiLD/TURN TO TARG~ WD=474 TM0=475 OEP=4 3C00 19.91 DLS: 4.00 deg per 100 ft 27.26 250C 54.88 42.62 50.44 ~000 E0C ~D=1649 TM0=1896 0EP=687 B/ PERMAFROST ~0=1789 TM0=2161 DEP=913 ' ,500 MAXIMUM ANGLE ] ~5'~ 58.11 DgG i s~c. :~. ~, ~o~ Begin Build/Tur~ to Tcrget 0 T/ W SAN SNOS W0=3719 TMD=5815 OEP=4014 ~ 5CC WSIO ~0=4124 TMD=6582 DEP=4665 C100 9 5/8" CSG PT ~VD=4324 TMD=6960 DEP=~987 CAMP. SS ~0=~521 TM0=7333 OEP=5303 C80 5500 60o0 J TARGET ANGLE 20 DEG 6500 70001 i 0 500 1000 1500 BEGIN ANGLE DROP TVD=498cj TMD=8219 OEP=6055 Z O 57.04 53.04 49.04 C50 45.04 OLS: 2.00 ceg per !CC 4! .04 C40 37.04 33.0'~ C35 29.04 C30 8/ HRZ TVD=6224 TMO=9901 OEP=7161 K-1 MARKER TVD=6315 TMO=IO000 DEP=7201 25.0~ T,O TVD=6426 TMD=10120 0EP=7246 TARGET - T/C4 (EOD) TVD=6466 yMD=10162 DEP=7257__k__2'-°* T/ C., TV0=6493 TM0=10191 DER=7270 .',,~ T/ C D 6 .,3 T 010 D 7 4, ~> T/ B SHALE l'VO=65gg TMD=10304 OEP=730g TD - CSG PT TVD=§68g TMD=10400 DEP=7342 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 Vertical Section {feet) -> Azimuth 327.85 with reference 0.00 N, 0.00 E from slot //17 c.-~o~ec =, ~;~c.~ For: F Johnsoz~ 2,ate D~o%tcd . 17-M~r-~8 Plot Reference ~ 17 V~sion ~2. Coard~ates ~re ~n feet ret~enCe ~ ~17. ~Tr~e Ve~col ~eot~s are reference RKO (~ 141).~ , ARCO Alaska, Inc. Structure : Pad 1C Well : 17 Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 480 440 400 360 320 280 240 200 160 120 80 40 0 40 80 120 1 §0 i I = ~ I 1 I I I ! I f I I I I I I I I I I I I ! I I I I i 1 48C 4-'0 ! 400 i 320 ~ I 280 i , 2~0 1 2C0 ~ I 8C 1 14OO 1800 '%,, 1600 · 1300 ,, 17O0 · '"', 1200 ",,, 1600 ',~ 1500 2700 "" 110£ ~600 '",, · 1000 2500 ,~0~'. ¢00 900 1 "",, 2300 "', 800 % '"', 2100 700 1300'-,, 2000 600 ", 1900 · . 170( 1200",~ 11 1000".. 560 520 480 L ~ 440 i L i I '-00 360 1 1500 i~ 320 i 1400 ~ 28O I A h I xnn~' 2~0 o . --~ ~- 200 oo L ~00 : ' ;50 ~oo ,, ..7_. "ec4 ,2° I ~- 80 I F i ~as~ Oil & Gas Cons. Commisslo~ An~hnr~n¢, , , ~ 160 160 , [ ~ ~ t ~ ~ ~ ~ ~ ~ [ ~ [ [ [ [ [ [ i · ] .... ~, ~ ~ , [ ] ; ] 480 4~0 400 360 320 280 240 200 160 120 80 40 0 40 80 120 160 <- Wesf (feel) { C~,o,,, ,~ ~,. For: F 1ohnsor~ O~e n~otted: 17-M~-98 ~ i P~ot Reference i~ 17 V~aion ~2. J ~ Ccoraina~es are in ~eet ref~ence ~ ~7. J ARCO Alaska, Inc. Structure : Pad lC Well : 17 Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 5200 5000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 , i I i I I I I I I I I I I I ! I I I I f I I I I I I I I ' I I ~°°~ ,,, ~oo J ',, ~ ~oo ~oool ', ~ ] '",, ~.5oo sooo d ", ~ ~oc ~oo~ '~, ~oo ~.oo ~oo "~ ~ '-4100 ,,~ 26OO 2600 '~'""~ 3100 290O ~ ,?oo V~oo ~o ~oo 5500 ~ 2CC0~ ",,,2700 ~ 2000 ~ x'"'X 2500 3, oo ,~ooq~ 'X X~°° ~,~oo ~ 700 . i ~soo ~ 'x X / ~200 : "' ~5 [ 1200 800 ~ F 8oo ~,ool 600 ~ "~ ~700 ~00 4uO ] ~ !500 400 d ~oo 3200 3000 2800 2600 2~00 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 <- Wesf (feel) g 0 i C~eatea ~y finch For: F ~'ohnso D~te plotted: !7-UQr-98 -- PIQt Reference ;. 17 V~Qn I ~ Coor~inotes Qre {n feet ref~ence ARCO Alaska, Inc. Sfructure : Pod 10 Well : 17 Field : Kuporuk River Unif Loco/ion : Norfh Slope, Alosko <- West (feet) 4600 4400 4200 4000 3800 3600 34-00 5200 3000 2800 2600 2400 2200 2000 : 800 ~ 600 6800 6600 6400 6200 6000 5800 5600 5400 I 5200 (]') 5000 ',-i.-- ¢' 4800 'E 0 z 4600 a400 4200 4000 3800 3600 3400 ! J 3200 4 "., 6500 '~, 6300 '~ 6100 %, 5900 \ '~ 5700 % 5500 ', ,, · 5300 \ · ,~ 5100 '., \ · I I t I I I I ] I I I I r ] i ' i : [ 6800 "A 4900 · '; 4700 "~ 4500 I i i i ~ i i i i i i d i i i i i i i i i i i i i i '\ 4300 · ,, \· · '~, 41 O0 'k 3900 ~ 3700 6700 65O0 6600 6400 h 6200 6060 5800 5600 5400 P 5200 I ~80C '-~ 6100 ~600 5900 i ~OO 5700 ' 4200 5500 ~OOC 5~00~ !3806 I 360C 340C , 3200 i , 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 <- Wesf (feel) ARCO Alaska, Inc. Pad 1C 17 slot #17 Kuparuk River Unit North Slope, Alaska MINIMUM DISTANCE CLEARANCE REPORT Baker Hughes INTEQ Your ref ; 17 Version #2 Our ref : prop2?51 License ~ Date printed : 17-Mar-98 Date created : 6-Feb-98 Last revised : 17-Mar-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 19 45.173,w149 30 19.124 Slot location is nT0 19 31.453,w149 30 2.691 Slot Grid coordinates are N 5968837.883, E 561567.906 Slot local coordinates are 1395.00 S 563.00 E Projection ty~e: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less ~han 500 feet DECREASING CLEARANCES of less than 1000 feet are ind/cated by an asterisk, e.g. 487.4* Object we11path PMSS (O-17089~,,,12,Pad 1C PMSS ~0-11300',,,11,Pad 1C GMS (O-9784~>,,7,Pad 1C MSS <0-7000'~,,gGI,Pad 1C GMS ,O-9600~m,,8,Pad 1C GMS (0-7780'~,,1,Pad lC GMS (0-7615~,,,2,Pad 1C PGMS ,0-9002'm,,10GI,Pad 1C G~MS ~0-9700~m,,3,Pad 1C GMS (0-7575'),,4,Pad lC GMS (0-?753~m,,5,Pad 1C M~S <6948-7570',,,WS#24,Pad 1C GMS ~O-10243'~,,6,Pad lC PMSS ~0-8677'~,,13,Pad 1C PMSS ~0-10980'~,,14,Pad 1C Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 7-Jan-98 182.5 100.0 100.0 19-Mar-97 185.4 100.0 100.0 5-Aug-92 220.4 250.0 250.0 2-Jan-98 20.3 462.5 462.5 5-Aug-92 182.2 100.0 100.0 5-Aug-92 863.7 250.0 250.0 5-Aug-92 745.9 250.0 250.0 5-Aug-92 134.5 0.0 0.0 5-Aug-92 630.7 250.0 250.0 5-Aug-92 517.1 0.0 0.0 5-Aug-92 407.4 100.0 100.0 17-Dec-97 11292.5 1700.0 2340.0 5-Aug-92 304.3 250.0 250.0 17-Feb-98 322.0 100.0 100.0 2-Mar-98 600.8 100.0 100.0 ARCO DOYON 141 13-518" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT MANUAL GATE 3" 5,000 psi WP Shaffer GATE VALVE wi hydraulic actuator / J DSA 13-5/8" 5m x 11" 3m L I I 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom / CHOKE LINE ~~0 psi WP OCT j_~~ MANUAL GATE VALVE 13-5/8" 5,000 psi WP DRILLING SPOOL ~ WI two 3" 5,000 psi WP outlets SINGLE 13-5/8" 5,000 psi WP, Hydril MPL BOP w/pipe rams Diverter Schematic Doyon 141 21%" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline 21%" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE / 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ~l~Vl DATE ! BY I CK lAPP'"' '. OESCRIPTION I REVl OATE I "1 CK lAPP I DESCRIPTION Z CONOUCTORS ARE LOCA~D ~IN C P F 1 -- ~ ~"~ ~/~'~- PRO~AC~D SECnON ~2, TO,SHIP 1, NOR~, I · · ' , ~ Nu'' ~ ~-~~~~ 4. OA~ OF'SUReX'3-9-98, FIELD BK:98-21 9~REZ ~ N ~ 56'20'37' ~ST FROM A.S.P. ZONE 4 GRID ~ [' / ?~ ? t [ L~F la 6. SEE OWG. NSK-3.~-~. FOR AS-BUILT /I q~ ? N ~oc~ no~s OF CONOUCrORS ~C-~-~C-a, S[E 0~C.~S~-~ 05. ~0~02 FOR ~S-aU~ r ~ClNI ~ MAP LOCATIONS OF CONDUCTORS 1C-9~ IC-~O. s[E o~.c~-o~cx-6~o~oa FOR ~S-aU~ r ~OC~r~ONS OF CO~OUCrORS ~C-~ · ~C-~2 · SEE OWC. C[~-O~CX-~O~O~5 FOR ~S-aU~r ~OC~r~O~S OF CO~OUCrO~S ~C-~ ~ ~C-~. Sec. 12, ~ 11 N., R. 10 E. We~ ~ 'Y' 'X' LA Ti TUDE L ONGI TUDE SEC. SEC. ELE~PAO ELE~O' C. FN.L?F.~L. ~7 5,968,8~8.00 56t, 568.78 XO' 19' ~1.454" ~49' ~0' 02.665" I.~95' 563' 60.5' 56.2' ~c OF ~x ~%. SURVEYOR'S ~ERTIFICA TE ~ ~" ~-%Y ~ REGISTERED ~ND LICENSED TO PRACTICE ~ ........................... D"~ ............ ~ ALASKA ~NO THAT THIS PLAT ' '"~~- ~as~ Oil & Gas Cons. Commi~Jol Anchorage LOUNSBURY ~ 1880CllT~S, I~C. ~EA' lC MODULE' XX UNIT' D1 'ARCO Alaska' Inc. ~' ~LL CONDUCTOR 1C-17 -_ AS-BUILT LOCA~ON CADD FILE NO. IDRA~NGNO: [SHEET: IREV: LK610317 3~10~98 CEA-D1CX-6103D17 2 oF 2 DESCRIPTION · ~S-PER KSB # K98016ACS LEGEND 0 EXISTING CONDUCTORS · NEW CONDUCTOR LOCATION OF..SCRIPTION 35 .36 T12N TllN Oil S.W.P.T. VICINITY MAP Pipeline SEE SHEET ~ 2 FOR NOTES AND LOCATION INFORMATION 1112q~ 8 '7 0 ~. ,3 6 17 00 13 10 0 N NO SCALE ARCO Alaska, Inc. CADD FILE NO. LK610517 5 0 4 0 14 0 3 0 2 0 1 0 LOUNSBURY & ASSOCIATES, INC. E~NEEI?.S PLANNERS SURVEYORS AREA: lC MODULE XX DRILL SITE 1-C WELL CONDUCTOR 1C-17 AS-BUILT LOCATION ! DRAWING NO: !SHEET: 3/10/98 CEA-D1CX-6103D17 1 OF 2 UNIT · 01 IREV: 1 ARCO KRU 1C-17 IWELL PERMIT WORK SHEET I INPUT AREA I hole csg csg size size wt. 20 16 62 12.25 9.625 40 8.5 7 26 6.125 4.5 12.6 J 3/23/98J csg csg csg top top bot bot ~lrd t&c I~lth md tvd md tvd . B Weld 80 . 28 28 108 108 L80 BTC 6932 28 28 6960 4324 L80 BTC 10022 28 28 10050 6356 L80 NSCT 550 9850 6179 10400 6690 AKRU 1C-17.xls design mud cmt, cfi ~rd, ppg Pf Cem 10.2 2286 10.2 93 9 45 12.5 I In, put Pressure/Depth Max bhp, psi J 3900 I tva, ft I 669o I grd.,psi/f 0.11 default 0.10 I csg csg size wt. 16 62 9.625 40 7 26 4.5 12.6 csg csg ~lrd t&c B Weld L80 BTC L80 BTC L80 NSCT Input Csg Paramenters coll. burst yeild pres. pres. st~th 670 1640 614 3090 5750 947 5410 7240 641 75OO 843O 288 annular bursFcoll ~~ Design Using Assumptions Factors Various I. Worst Case Design: Evacuated Pi )elEvacuated Annulus + 100K# overpull max coll. max burst wt yield csg coll. mud design burst fm design yeild of csg design size pres. press factor pres. press factor stgth +100k# factor 16 670 57 11.7 1640 63 26.0 614 105 5.8 9.625 3090 2293 1.3 5750 2521 2.3 947 377 2.5 7 5410 2975 1.8 7240 3705 2.0 641 361 1.8 4.5 7500 4349 1.7 8430 3900 2.2 288 107 2.7 0 0 0 0 0 0 0 0 0 0 0 0 0 0 II. Practical Case · Formation Pressure at Shoe- gas to surface wi mud in or outside casing. No overpull mud coll. max(res) burst ax(mud burst wt yield csg coll. less gas design burst surface design surface design yeild ofcsg design size pres. press factor pres. press factor press factor stgth +0k~ factor 16 670 46 14.4 1640 3190 0.5 57 28.7 614 5 123.8 9.625 3090 1861 1.7 5750 3190 1.8 2116 2.7 947 277 3.4 7 5410 2339 2.3 7240 3190 2.3 2642 2.7 641 261 2.5 4.5 7500 3680 2.0 8430 3190 2.6 3839 2.2 288 7 41.6 0 0 0 0 0 0 0 0 0 0 0 0 0 0 III. Cement Volumes and Heights Surf csg Surf csg csg csg ann cmt ht of csg/Inr top of w.r.t. Est'd cmt cmt size shoe vol,cE vol,cft cmt length cmt g.I. Fillup collapse collapse ,, 16 108 63 Pf Cern !!!!!..'!!!!!!!! 80 #VALUE! !!!!!!!!!!!!!! !!!!!!!!!!.-'!!! difl"l pres cdf 9.625 6960 2171 2286 7299 6932 339 above 1.1 795 3.9 i 7 10050 1271 93 733 10022 -9317 below 0.1 4.5 10400 52 45 478 550 -9922 below 0.9 0 0 0 0 0 0 0 0 Page 1 · WELL PERMIT CHECKLIST COMPANY ~,-'_,::~ WELL NAME/~'/-----/./~."-/,~ PROGRAM: exp [] dev'~redr, l [] serv [] wellbore seg C ann. disposal para re~) FIELD & POOL ~//~a'~:~i/~)~) INIT CLASS ~/'~,~, -./-.-~,z"// GEOL AREA ~,~ UNIT# ._/,~.&~"'"_~ ON/OFF SHORE ~ ~ ADMINISTRATION 1. Permit fee attached ....................... N .2._ Lease number appropriate ................... N 3. Unique well name and number .................. N 4. Well located in a defined pool .................. N 5. Well located proper distance from drilling unit boundary .... N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included ............... N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N 12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... N ENGINEERING APPR DATE 14. Conductor string provided ................... (~ N 15. Surface casing protects all known USDWs ........... (~ 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... Y N 19. Casing designs adequate for C, T, B & permafrost ....... (~ N 20. Adequate tankage or reserve pit ................. (~ N 21. If a re-drill, has a 10-403 for abandonment been approved... --Y-.-N- 22. Adequate wellbore separation proposed ............. (~ N 23. If diverter required, does it meet regulations .......... ~ N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ................ N 26. BOPE press rating appropriate; test to ~'~ psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ (:~ N P t ~/ 28. Work will occur without operation shutdown ........... (~ N 29. Is presence of H2S gas probable ................. N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... YY N J/~ ) z,~ 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. -33. Seabed condition survey (if off-shore) ............ .~ Y N 34. Contact name/phone for we.ekly,oro.qress reports ..... /. Y N lexplora'tory only] ,/ REMARKS GEOLO_GY: ENGINEERING: COMMISSION: BEWd'~(~ $/"2~ DWJ ~ JDH.~___ RNC~~.. c o Q) '//~-J,/~ Commentsllnstructions: HOWlljt - A:\FORMS\cheklist rev 09~97 ANNULAR DISPOSAL CHECKLIST COMPANY AJ~] WELL NAME ann. disposal para 1 ~ ann. disposal para 2 Il ¢l-:'"-©e~tie~-oPczcJLto_receive-~e ................ * 2. Depth to base of freshwater aquifers/permafrost ........ 3. Depth/thickness of receiving and confining zone ......... ? 4. Sufficient information to demonstrate confinement ........ Y - 5. List of all publicly recorded wells within 1/4 mile .......... Y ' 6. List of all publicly recorded water wells within 1 mile ........ Y - 7. Estimate of max. volume & density of waste slurry ........ - 8. Description of drilling waste ................ 9. Estimate of max. anticipated pressure at outer casing shoe .... - 10. Outer casing shoe set below aquifer/permafrost base ...... ~,~¢ 11. Outer casing shoe sufficiently cemented to provide isolation .... Y - ' ' o e/burst~'t'r~ n g t h ............ 13. Additional data .......................... Y N Ig ~ -l'V'L~ N Comments/Instructions:
