The URL can be used to link to this page

Home My WebLink AboutDIO 007 ~ /------. Conservation Order Cover Page XHVZE This page is required for administrative purposes in managing the scanning process. It marks the extent of scanning and identifies certain actions that have been taken. Please insure that it retains it's current location in this file. <\") - - - - . Conservation Order Category Identifier - l/lO-007 Organizing (done) RESCAN DIGITAL DATA OVERSIZED (Scannable with large plotter/scanner) 0 Color items: 0 Grayscale items: 0 Poor Quality Originals: 0 Other: 0 Diskettes, No. 0 Maps: 0 Other, Norrype 0 Other items OVERSIZED (Not suitable for plotter/scanner, may work with 'log' scanner) ~ Logs of various kinds 0 Other NOTES: DA"fp I~~ D1f TOTAL PAGES 7c¿ @ Dmb/~f)t¡- Ie) IMP Production Scanning ~d {. Au-=t/~Qj}. ~.) Stage 1 PAGE COUNT FROM SCANNED DOCUMENT: I ð ~/ / . PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: LX YES NO /- - // hVM^,~ DA" ~ f~ ( ,,' Stage 2 IF NO~ STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: 1- YES - NO /s/ V11P ~ BY: ./' ~ Scanning Preparation BY: BY: BY: ...ARIA DATE: /s/ 'V . (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REOUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO OUALm', GRAYSCALE OR COLOR IMAGES) General Notes or Comments about this Document: 5/21/03 ConservOrdCvrPg.wpd W. McArthur D:1' freeze protect question . .\~ d Subject: W. McArthur D-l freeze protect question Date: Mon, 11 Oct 1999 10:47:13 -0800 From: Wendy Mahan <Wendy_Mahan@admin.~tate.ak.us> '"' '~\.\ð ~? Organization: doa-aogcc --LJ '~ To: fenl0@pobox.alaska.net CC: Robert Christenson <robert_christenson@admin.state.ak.us>, David Johnston <davejohnston@admin.state.ak.us>, Camille Oechsli <cammy _ oechsli@admin.state.ak.us> Mr White, You have asked the Commission if you can freeze protect disposal well 0-1 with the following: 2 bbls glycol in the tubing with 1 bbl diesel on top, and 2 bbls diesel in the annular space of the well. As described, the "new product" diesel and glycol will be used solely to freeze protect the well. Non "Class II" fluids may be injected into a well as long as they are necessary for the maintenance or operation of that well. Please call me at 793-1236 if you have any additional questions. Wendy .... .. SCANNED JUl 0 2 2004 lof! ! 0/12/1 999 3 :23 PM . - .!,,, ~ ~~, 1::>10 -7 TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501·3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 8, 1998 Paul White Drilling Manager FORCENERGY Inc. 3 10 K Street, Suite 700 Anchorage,AJ< 99501 Re: Request for approval to inject sanitary waste in WMRU D-l. Dear Mr. White: This letter is in response to your July I, 1998 letter requesting approval for disposal of sanitary wastewater into West McArthur River Unit disposal well 0-1. Treated sanitary wastewater is not authorized for Class II disposal. The Commission may approve injection into a Class II enhanced recovery well upon showing that the treated sanitary wastewater is compatible with formation fluids and that it will not impair the mechanical integrity of a well. Please feel free to contact the Commission if you need further clarification. "- David W. Jò Chairman SCANNED JUt. (} 2 2004 ~.- .-t~,1~,~:~~ .,,,,;~...,. . , Inc -- ." July 1, .1998 Alaskã Oil and Gas Conservation Commission 3001 Porcupine Drive . Anchorage. Alaska 99501 /_,.._ºNL.Y . Chair .~õ-~ Comm tD ¡....... , File 10-'" Attn: Commissioner Oechsli Re: West McArthur River Unit#D1-lnjection Well "'^ÍÅ"ìfii\~fÐ ø-!JfP'\~~\ Cc.: ~ lJ~ Commissioner Oechsli ~ ',~ ~.. ¡,.~..... Forcenergy is currently operating the West McArthur River Unit#D1 well' for disposal purposes at the West McArthur River production facility. This wellîs operated under Disposal Injection Order #7, dated April 19, 1993. The well is injecting produced water from West McArthur River Unit #1A, 2A and 3ST. We.are:reqyestLñg¡th'ij) áddition;of:sàñita!y Wåst~~!2ìth:è~~ÞlõyeCl:wásterstr~_ª-I'DJörl\tYëI1~#D~1~ This waste would be generated from the small camp presently used by our production personnel. -- ... _. J. If there are any questions, please contact me at 907-258-8600. Q~~ - Paul White Drilling Manager Forcenergy Inc. RECEIVED JUL G 1 1998 Alaska Oil & Gas Cons. Commission , Anchorage Date Modified: 7/1/98 Date Prepared: 7/1/98 rs \\FGEANCH\SYS\ACCT\RSTINSON\WMR Injection Letter.doc HEADQUARTERS ;·Forcenergy Center .,- 2730 SW 3rd Avenue ~.Suite 800 ~.~iami, Florida 33129-2237 $r;A~Nr:D JUL !} 2 2004 REGIONAL OFFICE TELEPHONE 305/856-8500 FAX 305/856-4300 310 K Street Suite 700 Anchorage, Alaska 99501 TELEPHONE 907/258-8600 FAX 907/258-8601 ,;t' "--- ,- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: The REQUEST OF STEWART ) PETROLEUM COMPANY to dispose) of Class II oil field fluids by ) underground injection in the West) McArthur River 0-1 well. ) Disposal Injection Order No.7 West McArthur River 0-1 well April 19, 1993 IT APPEARING THAT: 1. Stewart Petroleum Company by correspondence dated March 3, 1993 made application to the Alaska Oil and Gas Conservation Commission (AOGCC) for authorization to inject Class II waste fluids into the West McArthur River 0-1 well. 2. Notice of an opportunity for public hearing was published in the Anchorage Daily News on March 5, 1993. 3. No protest or request for a public hearing was timely filed. FINDINGS: 1. No wells penetrate the proposed injection zone within a one-quarter mile radius of the West McArthur River 0-1 well (WMR 0-1). 2. Cook Inlet Region, Inc., State of Alaska, Salamatof Native Association, Inc., and Phillips Petroleum Company are offset operators and surface owners within a one-quarter mile radius of the WMR 0-1 and have been duly notified of the proposed plans. 3. CIRI has designated Stewart Petroleum as operator of the WMR 0-1. 4. The WMR 0-1 was drilled to the subsurface estate of Cook Inlet Region, Inc. (CIRI) to a total depth of 4502 feet measured depth. 5. The Tyonek Formation consisting of Lower Tertiary aged, massively bedded, fluvial deposits is present within the WMR 0-1 from approximately 3000 feet measured depth to total depth. .~ Disposal Injection 01. ..,,' No.7 April 19, 1993 Page 2 ~ 6. A highly porous and permeable sandstone with calculated porosity and permeability of 32 percent and 1600 millidarcies respectively is present from 4283 to 4351 feet measured depth (4120 to 4188 feet subsea). 7. Formation water with total dissolved solid (TDS) content of at least 11,800 parts per million (ppm), as determined by EPA method 160.1, is present in the sandstone occurring from 4283 to 4351 feet measured depth. 8, An impermeable confining zone composed of shale, coal and minor discontinuous sands and siltstones is present in WMR 0-1 from 4184 to 4282 feet measured depth, 9. Open hole wireline log analyses and EPA-approved laboratory analyses of formation water samples indicate underground sources of drinking water (USDWs) are present (TDS < 10,000 ppm) to 4184 feet measured depth (4021 feet subsea) in WMR 0-1. 10. Openhole wireline log analyses indicate the deepest non-exemptable aquifer (TDS < 3000 ppm) occurs at a measured depth of 1335 feet. 11. Nine and 5/8-inch surface casing string is set at 1361 feet measured depth, cemented to the surface and tested to 2500 psi. 12. Seven-inch casing is set at 4500 feet measured depth and cemented to at least 2000 feet above its base. 13. Two and ll8-inch tubing with packer is installed, with the packer set at 4197 feet measured depth. 14. With tubing and packer in place, the 7 -inch casing was pressure tested to 1000 psi. 15. Cement evaluation tools run in WMR 0-1 indicate good to excellent cement bond over most of the cemented interval of the 7 -inch casing string. 16. The operator estimates that the injection rate will not exceed 6000 bbllday. 17, The estimated average operating pressure will be 800 to 1000 psi and the maximum anticipated surface injection pressure will be 1115 psi. ~ ,,--. Disposal Injection 01.. ,'No.7 April 19, 1993 Page 3 18. A three-dimensional hydraulic fracture simulator run at rates and pressures exceeding those planned in the WMR 0-1, due to wellhead and equipment limitations, indicates induced fractures will not propagate through the overlying confining zone. 19. A mechanical integrity test has not been performed on WMR 0-1. 20. The operator plans to monitor the 7 -inch casing by 2 7/8-inch tubing annulus pressure and report the results on the Monthly Injection Report. 21. Prior to commencing injection operations in WMR 0-1, the operator plans to perform a step rate test in order to determine the formation fracture gradient and optimum injection rate. CONCLUSIONS: 1. The approval of disposal injection operations at WMR 0-1 will not jeopardize correlative rights. 2. Permeable strata which reasonably can be expected to accept injected fluids at pressures less than the fracture pressure of the confining strata are present in the interval from 4283 to 4351 feet measured depth in WMR 0-1. 3. The interval from 4283 to 4351 feet measured depth in WMR 0-1 does not qualify as a USDW. 4. An impermeable confining zone is present in WMR 0-1 from 4184 to 4282 feet measured depth. 5. Disposal fluids injected at WMR 0-1 will consist exclusively of Class II waste generated from drilling, completion and production operations. 6. WMR 0-1 is constructed in conformance with the requirements of 20 AAC 25.412. 7. Well integrity must be demonstrated in accordance with 20 AAC 25.412 prior to initiation of disposal operations in WMR 0-1. 8. Operational parameters will be monitored routinely at the WMR 0-1 for disclosure of possible abnormalities in operating conditions. ~ Disposal Injection Or, .,' No.7 Apri119,1993 Page 4 r-\ 9. No application for a freshwater aquifer exemption is required in conjunction with the proposed disposal injection project in WMR D-1 because TDS content exceeds 10,000 ppm for the formation fluids within the proposed disposal zone. 10. Disposal injection operations in the WMR 0-1 will be conducted routinely at pressures less than disposal zone parting pressure. NOW, THEREFORE, IT IS ORDERED THAT: Rule 1 Authorized Injection Strata for Disposal. Class II oil field fluids may be injected in conformance with Alaska Administrative Code Title 20, Chapter 25, for the purpose of disposal into the Tyonek Formation interval from 4283 to 4351 feet measured depth in WMR 0-1. Rule 2 Demonstration of TubinglCasing Annulus Mechanical Integrity Prior to initiating injection and at least once every four years thereafter the tubinglcasing annulus must be tested for mechanical integrity in accordance with 20 AAC 25.412. Rule 3 Well Integrity Failure Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation, obtain Commission approval of a plan for corrective action and obtain Commission approval to continue injection. Rule 4 Step Rate Test Prior to sustained injection the operator shall perform a step rate test to determine a formation fracture gradient and optimum injection pressure. Rule 5 Administrative Action Upon request, the Commission may administratively revise and reissue this order upon proper showing that any changes are based on sound engineering practices and will not result in an increased risk of fluid movement into an underground source of drinking water. ~ .'~ Disposal Injection Or. , No.7 April 19, 1993 Page 5 DONE at Anchorage, Alaska and dated April 19, 1993. ~ (). LL--~ Russell A. DouglaS~, Gottmissi~n Alaska Oil and Gas Conservation Commission #8631 STOFO330 AO-O85734 /"" ~ AffIDAVIT Of PUBLICATION ........... ......... .......... ...,......... .....,.. ,;!I.nchoN!9êi.l5. !I~sf;t,h~'ad ,att~r. IfAhêC'prQj'esf> i$Aim~ly fil~d , ðh<tfaise$" a. SIÞstllntialand !!1l1tðr¡aíi~slÍ~¿ruéiâl,to th~ Comi1'iission's 'd~t~rminatiQn, ah~ariÌ1got\'th.~",matt~r- will beh~ld 'attheaÞove 'addr~ss at9:00AMOJl ,4¡pril6i1993 in (orifolm,ancllw.ith -20' AAC . 25.540:011 a Maring-is to be "~Idi .i't\t~r~st~d', þarti~S - may corìfirm' this, -by <calling, the Commjssion~s' offic~, . (907) , '279'1433 aft~rMarc,h22, 1993. If no Prot~st isfil~d,th~,Com. missiollwlliconsi"d~rtMissl' ance,of th~ ord~r without a hearing.-.""" , is/Russell A Douglass CQmmjssion~r Alaska Oil and Gas Cons~rvationCommìssìOn Pub!. March 5; 1993 STATE OF ALASKA. THIRD JUDICIAL DISTRlCf. Eva M. Kaufmann being first duly sworn on oath deposes and says that he/she is an advertising representative of the Anchorage Daily News. a daily newspaper. That said newspaper has been approved by the Third judicial Court. Anchorage. Alaska. and it now and has been published. in the English language continually as a daily newspaper in Anchorage. Alàska. and it is now and during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on March 5, 1993 and that such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. ,;gned f~. ~ Subscribed and sworn to before me this g~day o~. 1993- ~~ ¡J dÞ.axun. NoraVpublic In and for the State of Alaska. Third Division. Anchorage. Alaska MY COMMISSION EXPIRES REfEIVED MAR 1 0 1993 Alaska Oil & Gas Cons. Commission Anchorag$ MY COMMISSION EXPIRES . ........ .JULY..24,.19.96.. ......... ....19,..... r" Stewart Ee,woleum ompany ,. ' Denali TõW~rs North, Suit~ 1300 2550 Denali ßt?~ét, Anchorage, ,; aska 99503 (907) 27'i';.4004 . FAX 907) 4-0424 '. . APPLl'CA'10~'FåR'ÐISPOSAL INJECTION ORDER Stewart Petroleum Company' West McArthur River Unit No. D-1 r-' 'Submitted to Alaska Oil and Gas Conservation Commission Prepared by . ' ËNSR Consulting and Engineering " , ~ J ~ March 1993 J EN:R E\,SR Consulting and Engineering, 4640 Business ParkBlvd. Building D. . .t,l1êh(}ra.?e;'1\~ 99503' , - {OO7r?6V~700" :FAX (9\{1)'Z73-4555 ,,- .'. ...--. ' I' March 3, 1993 ENSR Ref. No: 6397 ~003.400 ENSR Doc. No: 930064 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RECE\VED Attention: Commissioner David Johnston, Chairman MAR - 3 1993 Re: AlasKa ulI& Gas Cons. Commission Application for Disposal Injection Order ' Anchorage by Stewart Petroleum Company ,,' " ,., West McArthur River No. D-1 Well, Coo~ lBi§tt.J:1a&in . :,,',:J:':,Ù;; '-~~. Dear Commissioner Johnston: - ::, "i\rr"':'",- " ~ Stewart Petroleum Company, as operator of the West McArthur. ßiv~rU'nlt~-I}~ret;)Jmakes application for a Disposal Injection Order to authorize the i~~~~~~~g~~~~(fJl:~~cfänd -,' production wastes into the above referenced well. These w~ß.t~~W¡t9J'fgenê',:ata<Hr()m ' delineation, and develop~ent ~rilling within the West McArth,~~"~X~iJL~Q~¡r~Wrlì. ~~) was recently drilled as a stratigraphic test of the upper part of the TYQn~~ß forIn~!lqn(an.#)or the purpose of identifying and evaluating subsurface zones suitable for the irijeCtibn of Class II wastes. A suitable injection zone has been identified between 4,289 ft and 4,351 ft in the D~1 well. This zone was perforated and formation fluid samples obtained. TDS ¡nthese fluids is approximately 11 ,800 ppm. This zone is intended to be used for the disposal of drilling "" wastes as soon as the Disposal Injection Order is issued. Other Class II wastes, -such as produced water, may also be disposed in the well at a later date. In the~vent at some future date this primary zone becomes unsuitable for the injection of wastes,. the well may be deepened, and another zone between 4,500 ft and 5,000 ft would be' accessed. ,~-, The attached information supporting this application has been prepared in accordance with AAC 25.250 to demonstrate that Well 0-1 has been drilled, completed, and will be operated in a manner that will prevent the movement of injected fluids into fresh water. .. -:"~,, E,.-. ...----. , March 3, 1993 Alaska Oil and Gas Conservation Commission Page 2 If you have any questions regarding this application, please contact the undersigned or Jesse Mohrbacher at 561-5700. Thank you for your consideration of this application; , slnce~~.IY' '. ..7 ~ R,C. Gardner Regional Program Manager Oil and Gas Services (Agent, Stewart Petroleum Company) RGjlw ,~,---- Attachment cc: W,R. Stewart, Stewart Petroleum Company -,~..~---. r---- ..,.../""-""'- .....,r' c-..-'" " : Stewart P~tfoleum yompany Denali 'Ì'õwêrs North, Suitk 1300 2550 Denali ~t?ê"'et, Anchorage, Alaska 99503 (907) 2740.4004. FAX (907) 2:74-0424 ~~, !)-~'^' ~ tß \ ~ ~ ~.J February 1, 1993 Re: West McArthur River Unit Area and all wells drilled within this Unit Area or in the vicinity of the Unit Area. Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 ,~'-, Attn: Mr. Robert P. Crandall Senior Petroleum Geologist Gentlemen: The purpose of this letter is to confirm that Mr. Robert C. Gardner, individually, and ENSR Consulting and Engineering have been designated agents of Stewart Petroleum Company and are authorized to represent Stewart Petroleum Company in all matters before the Commission with respect to the captioned area. This authorization includes, but is not limited to, execution and filing of any and all required reports and appearances before the Commission as necessary. These authorizations shall remain in full force and effect until revoked or modified in writing by Stewart Petroleum Company. Thank you for your cooperation in this matter. Sincerely, ~ ,C~CC W. R. Stewart President WRS:nl cc: R. C. Gardner (ENSR) r" Stewart Petroleum Company Denali Towers North, Suite 1300 2550 Denali Street, Anchorage, Alaska 99503 (907) 277-4004 . FAX (907) 274-0424 APPLICATION FOR DISPOSAL INJECTION ORDER Stewart Petroleum Company West McArthur River Unit No. D-1 ~ Submitted to Alaska Oil and Gas Conservation Commission Prepared by ENSR Consulting and Engineering ..----., March 1993 ."'-", CONTENTS 1.0 PROPERTYPLAT ...............................................,1-1 2.0 LIST OF OPERATORS AND SURFACE OWNERS.. . . . . . . . . . . . , , , . . . . . . , . 2-1 3.0 AFFIDAVIT....,...,.............................................3-1 4.0 GEOLOGIC INFORMATION .........................................4-1 4.1 Quaternary..................................................4-1 4.2 TertiaryAge .................................................4-1 4.3 Beluga Formation ..,....................................,...., 4-1 4.4 TyonekFormation..........,.....,................,....,..,...4-2 5.0 WELL LOGS .................................................... 5-1 6.0 CASING AND CEMENTING PROGRAM ................................6-1 ,'~'" 7.0 INJECTION FLUID ................................................7-1 8.0 INJECTION PRESSURE .........,.......,....,.....................8-1 9.0 FRACTURE INFORMATION ...............,.....,.................,.9-1 10.0 FORMATION FLUID .............................................10-1 11.0 FRESHWATER AQUIFER EXEMPTION..................,......... ,..11-1 12.0 MECHANICAL INTEGRITY .................,...."................12-1 13.0 WELLS WITHIN AREA ........................,..................13-1 ~" 4-1 6-1 7-1 7-2 LIST OF TABLES West McArthur River No. D-1 Disposal Zone Confining Layer Summary. ,...,.. 4-5 Casing & Cementing Program Summary, Stewart Petroleum West McArthur RiverNo.D-1. ...........................................,....,.6.3 Waste Drilling Fluid Composition. ...........,........................7-3 Completion Fluid Composition. ....................................,7.4 ii .,--', 1-1 1-2 6-1 13-1 13-2 13-3 13-4 '-~', "~-', LIST OF FIGURES Surface & Bottom Hole Locations for Area Wells. ............,........... 1-2 Measured & True Vertical Depths for Area Wells. . . . . . . , . . . . . . . . . , . . . . , . ,. 1-3 West McArthur River Well D-1 Schematic Diagram. .................,.,... 6-2 West McArthur River Well D-1 Schematic Diagram. ..... . . . . . . . . . . . . . . . .. 13-2 Schematic of West McArthur River Unit No.1 Well. . . . . . . . , . . . . . . . . . . . . .. 13-3 Schematic of Pan American West Foreland Unit No.2 Well. ,....,.,....... 13-4 Schematic of Proposed West McArthur River Unit No.2 Well. """"""" 13-5 iii ~, 4-1 ~" ,~. LIST OF PLATES Well Log Correlation. ............................................, 4-4 iv ."---', 1.0 PROPERTY PLAT The surface and bottomhole locations for existing and proposed wells in the West McArthur River Unit area are shown in Figure 1-1. There are no wells that penetrate the proposed injection zone (4,289 ft to 4,351 ft) within one-quarter mile of the West McArthur River No. 0-1 well. Figure 1-2 identifies the measured depth (MO) and true vertical depth (TVO) for each well within one-quarter mile of the 0-1 well and at the proposed disposal zone depth of 4,289 ft TVO. ."---"" -"-. 1-1 \ ~Q' 'Ù~~ ~ç,,~ ~ ~'Ù~ ~';\ ~c~ c:,~ SEC. 1 6, ~ç; TaN, R14W. S.M. 5280 FT. : ~\O '2. g I SEC. 14 u~\1 \' . . "O50Õ- R\\(€.R I cÞ-R1\,\uR I 'N€.51 '-' -L:j660 FT. I o?O5€.O ß- I I . I .. -----SEC. 15------ :II T8N, R1~W. S.M. e) ., I WEST FORELAND 3300 FT. I UNIT NO.2 I 2~7 I I I West McArthur River Unit No.1 end 2 wells occupy the same surface location as the West McArthur River No. D-1 well. Surface location measurements shown above are for West McArthur River No. D-1 well and West Foreland Unit No.2 well. ~. COOK INLET SEC. 9 SEC. 17 .-. WEST McARTHUR RIVER NO, D-1 (STRAIGHT HOLE) 1/4 MILE RADIUS AROUND D-1 WELL (SEE FIGURE 1-2) / - 1953 - SEC. 21 NOTE: EN:R ENSR CONSULTING & ENGINEERING DRAWING: PSBH2 DRAWN: SR/ABB/JL C/SC: 1:2300 DISK: D/S1S DATE: 03/01/93 CHECK: JM SEC. 3 ADL 359111 STEWART PERTOLEUW CO. 11-30-90 2763 FT. t: ADL 17602 ARCO et 01 HBU .. .. ... on 5280 FT. SEC. 11 1572 FT.- SEC. 22 SEC. 23 COOK INLET BLUFF 0 1000 2000 I I SCALE IN UNITS FIGURE 1-1 SURFACE & BOTTOM HOLE LOCATIONS FOR AREA WELLS STEWART PETROLEUM CO. WEST McARTHUR RIVER UNIT PROJECT 6397-003-400 1-2 ~v. ~~ , SEC. 16, +°' ...0=-4910 ~ OEPTH Of' TaN, R14W, S.t.A, ~~~ TVO=3850 S INJECTION ZONE ~\.\.P"'\\ ~,~~ ~o. '1 ~ ~" of 1\ \I~\1 ...0=3195 -. v.~~ /0=4850 lot""" o~ 1.0~t '\'I\I~ P,1'It TVO=27 I 3 ..~~ TVD=3950 S ,~JtC" 51 ~ç"p, ¥t. I stO ~t ~~ p~OfO ~ ...0=3200 .r-. 660 FT. ,~ ~ ,/ TVO=2763 . -\ ~:\~ . "'0=2700 ~~~ TVD=2672 '\0. . o. t WEST f'ORELANO UNIT ~ 0 LO=-4310 l OEPTH Of' ~ TVO=-4065S INJECTION ZONE SEC. 17 -- 1-4-46 ...... ¿., ~'~UNMDILE RAOIUS f' M WEST cARTHUR RIVER / NO. D-I J 2776 .. -- 1953 --- NOTE: Depths depIcted above represent the measured depth (1.10) and true vertical depth (TVD) for each well path within 1/4 mile of the West McArthur RIver No. 0-1 well and at the disposal zone TVO of 4289 It. Surface location measurements shown above are for the West McArthur River No. 0-1 well and the West foreland Unit No.2 well. EtaI ENSR CONSULTING & ENGINEERING DRAWING: I.ITV C/SC: 1:1500 DATE: 02/26/93 DRAWN: SR DISK: 0/572 CHECK: JI.I 2047 " ') ') . / t 0 GO N It) SEC, 9 10 SEC. 5280 f'T, SEC. 15 3300 f'T, " SEC. 21 SEC, 22 0 750 1500 I I SCALE IN FEET FIGURE 1-2 MEASURED AND TRUE VERTICAL DEPTHS FOR AREA WELLS STEWART PETROLEUM CO. WEST McARTHUR RIVER UNIT PROJECT 6397-003-400 ,---- 2.0 LIST OF OPERATORS AND SURFACE OWNERS The following operators and surface owners are located within one-quarter mile radius of the West McArthur River No. 0-1 well: ~, . Stewart Petroleum Company Denali Towers North, Suite 1300 2550 Denali Street Anchorage, AK 99503 . Cook Inlet Region, Inc. (CIRI) 2525 C Street P.O. Box 107034 Anchorage, AK 99510-7034 . Salamatof Native Association, Inc. 110 Willow Street, Suite 105 Kenai, AK 99611 . Phillips Petroleum Company P.O. Drawer 66 Kenai, AK 99611 . State of Alaska Department of Natural Resources Division of Oil and Gas P.O. Box 107034 Anchorage, AK 99510-7034 The West McArthur River No. 0-1 well is operated by Stewart Petroleum Company and drilled on the subsurface estate of Cook Inlet Region, Inc. (CIRI). A Designation of Operatorship for the 0-1 well is provided on the following page. It is anticipated that this agereement will be signed by CIRI on or before March 5, 1993. Two signed originals will then be submitted to the AOGCC. ~, 2-1 ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DESIGNATION OF OPERATOR 20 AAC 25.020 1. Name of Owner COOK INLET REGION, INC. 2. Address 2525 C street P.o. Box 107034 Anchorage, AK 99510-7034 3. Notice is hereby given of a designation of operatorship for the oil and gas property described below: Property designation: Subsurface estate of Cook Inlet Region, Inc., for purpose of operation of West McArthur River Well D-1 for Injection/Disposal Operations only. Legal description of property: NW 1/4, Sec 16, T8N, R14W .~ Property Plat Attached 0 4. Name of Designated Operator STEWART PETROLEUM COMPANY Address Denali Towers North, Suite 1300 2550 Denali Street Anchorage, AK 99503 5. Effective date designation March 3, 1993 6. Acceptance of operatorship for the above described property with all attendant responsibilities and obliga. tions is hereby acknowledged # Signed R. C. Gardner Title Agent, stewart 7. The owner hereby certifies that the foregoing is true and correct petroleum Co. Date 3/3/93 "r---, Signed Carl H. Marrs Form 10,411, 12,1-85 Title Senior Vice-President Date Submit in Duplicate - 53 - ..,r-. , 3.0 AFFIDAVIT The following page contains the affidavit of Mr. R. C. Gardner, Agent for Stewart Petroleum Company, as required by 20 AAC 25.252(c)(3). ./""-', 3-1 r---, AFFIDAVIT OF R.C. GARDNER AGENT FOR STEWART PETROLEUM COMPANY STATE OF ALASKA THIRD JUDICIAL DISTRICT I, RC. GARDNER, DECLARE AND AFFIRM that I am Agent for Stewart Petroleum Company, that I have personal knowledge of the matters set forth in this affidavit, and that on the -3 ",ui, day of March, 1993, the following operators and surface owners were provided a copy of this permit application: Cook Inlet Region, Inc. 2525 C Street P.O. Box 107034 Anchorage, AK 99510-7034 Salamatof Native Association, Inc. 110 Willow Street, Suite 105 Kenai, AK 99611 ~. State of Alaska Department of Natural Resources Division of Oil and Gas P.O. Box 107034 Anchorage, AK 99510-7034 Phillips Petroleum Company P.O. Drawer 66 Kenai, AK 99611 by placing said copy in the United States Mail with postage prepaid and certified at Anchorage, Alaska. ~~ RC. Ga~ SUBSCRIBED AND SWORN to before me this 3.4 day of March 1993. !-~ Notary Public in and ."--". -,.., Oomml..lon ExÞlrea: Octobtr 2t, 1991 My Commission expires .r--" 4.0 GEOLOGIC INFORMATION 4.1 Quaternary The Quaternary deposits in the vicinity of the well location are a thin veneer of inter-mixed glacial debris, stream gravels, volcanic ash falls and plant remains. Both the glacial and stream deposits are very unconsolidated and are a poorly sorted mixture of clay, silt, sand and cobbles. Huge angular igneous boulders, are locally present, which were dropped during glacial advances. The volcanic ash debris occurs as stream and airborne deposits, They were derived from the nearby volcanoes. Because of the unconsolidation of the Quaternary, the fresh water runoff is at maximum and disappears quickly, percolating downward through the mantle. Contamination risks would be a concern in these deposits. Electric logs show high resistivity with little or no spontaneous potential curves. Slow seismic velocity time is also prevalent in the unconsolidated mantle. 4.2 Tertiary Age ,----.. Tertiary age rocks in the Cook Inlet basin are consigned to the Kenai Group. The Group is predominantly nonmarine and consists of the (youngest to oldest) Sterling, Beluga, Tyonek, Hemlock, and West Foreland formations. The Sterling is absent in the West McArthur River Unit area. 4.3 Beluga Formation The quaternary deposits rest unconformably on the Beluga formation. The formation is characterized by thin intercalated beds of claystone, siltstone, sandstone and lignitic to subbituminous coal. A few medium bedded sandstone and coal beds in the upper part of the formation are productive in the Beluga River gas field. However, these producing strata are believed to be absent in the Stewart Petroleum discovery well, West McArthur River Unit No.1, and in the West McArthur River 0-1 well. The 0-1 well was drilled as a stratigraphic test to evaluate zones that would be suitable for the injection and disposal of Class II drilling wastes. ,~-. 4-1 ,--. 4.4 Tyonek Formation The Tyonek unconformably underlies the Beluga formation. The massive sandstone and coal beds present in the Tyonek distinguish it from the Beluga. The sandstone is fine to medium grained, interbedded with bentonitic claystone, siltstone and lignite to subbitumenous coal. The sandstone is light to medium gray, loosely cemented by a bentonitic clay matrix. Coarse sand grains and pebbles are scattered throughout the sandstone along with volcanic rock grains. Many of the coal interbeds reach a thickness in excess of 20 ft. The Tyonek is encountered in the West McArthur River No. 0-1 well at approximately 3,000 ft TVO. r" At a true vertical depth of 4,289 to 4,351 ft in the 0-1 well, a permeable sandstone bed occurs in the Tyonek. This particular sandstone was depicted from the electric, geologic sample, and mud logs. The calculated porosity and permeability of this sandstone is 32% and 1,600 md, respectively. No oil and gas shows occur in this interval, and the formation fluids measure approximately 11 ,800 ppm total dissolved solids (TOS). The sand beds are both over and underlain by a series of tight interbeds of claystone, siltstone and coal. The nature of these impermeable beds will prevent any intermingling between of waste fluids and the connate waters of the younger and older rocks. Given the above geological conditions, it is recommended that this sandstone be used for the disposal of Class \I drilling and production wastes generated from delineation and development drilling within the West McArthur River Unit area. The proposed disposal zone has been identified to be continuous throughout the West McArthur River Unit area. Well logs from the West McArthur River 0-1, Unit No.1, and Pan American West Foreland Unit No.2 have been correlated on Plate 1 at the end of this section. These well log correlations identify the proposed disposal zone and the associated confining layers between the disposal zone and the base of the nonexempt fresh-water aquifers « 3,000 ppm TOS). The Spontaneous Potential (SP) method was used to calculate TOS values in each of the sandstone beds near the nonexempt aquifer transition area, and these values are annotated on the well log correlation plate. The nonexempt fresh-water aquifer transition occurs between 1 ,280 ft and 1 ,490 ft in the 0-1 well. Aquifers with less than 3,000 ppm TOS have been cased off by the surface casing, which was set at 1,364 ft. "r--, Numerous shale (clay, mudstone, and siltstone) and coal confining layers are present between the proposed injection zone and the base of the nonexempt aquifers. The vertical distance between these two zones is 3,009 ft (4,289 ft-1 ,280 ft). The confining layers are identified on the well log correlation plate and summarized in Table 4-1. Confining layers account for a minimum of 43% (1 ,293 ft) of the strata between the disposal zone and the 4-2 ."'-""'. base of the nonexempt aquifers. Confining layers are also discussed later under Fracture Information. .'--'" ~- 4-3 -'~' TABLE 4-1 west McArthur River No. 0-1 Disposal Zone Confining Layer Summary :çÞI;I~II!!!ly~t¡I:I¡1 CL-1 CL-2 CL-3 CL-4 CL-5 ........,......'..,..'"",'.."",..".., ..,....,..,..,....,..,...."..',..'""", ...,........,.., """"""""",,"". ....."..,....,..,..,...."...."",...." """"".",..,.,...""""""""". , ::.:'.,::;::::Iiêm.{fj):: 4270--4285 4246--4270 4184--4230 4150--4160 4144--4150 ,.---, CL-6 4119--4144 CL-7 3955--4119 CL-8 3930--3945 CL-9 3906--3930 CL-10 3821--3842 CL-11 3680--3703 CL-12 3660--3680 CL-13 3534--3542 CL-14 3360--3370 CL-15 3270--3300 CL-16 3191--3212 CL-17 3100-3120 CL-18 3130--3152 CL-19 3062--3085 CL-20 3045--3055 CL-21 2890--2958 CL-22 2773--2873 CL-23 2650--2740 CL-24 2614--2622 CL-25 2583--2614 ".r---., I:I.::I!'.:¡.I::¡ :::::!:il¡~lfil~;!.!!{ll....!¡.¡.¡.¡!.!..:...!I.¡.:::¡¡ .¡:.:::ltim~i.¡.~i!ÞøJi~ý:...:... 15 Shale 24 Coal 46 Shale 10 Coal 6 Shale 25 Coal 164 Shale 15 Shale 24 Coal 21 Shale/Coal 23 Shale 20 Coal 6 Shale/Coal 10 Coal 30 Shale 21 Shale 20 Shale 22 Shale 23 Shale 10 Shale 68 Shale 100 Shale/Coal 90 Shale/Coal 8 Coal 31 Shale 4-4 TABLE 4-1 (Cont'd) ,~, West McArthur River No. D-1 Disposal Zone Confining Layer Summary ~øij1iri!ðl:III~I:: CL-26 CL-27 CL-28 CL-29 ......,..,..""'..',,....,....,............, ......,..",'....,....,..........,....,.."", ..,..'""",'..','......,..,......,....".., " '" " , ' , ,. '. "".""..""", " " '" " , '" ' ....,..",.............,..........,..,'...., m6~çRÔ!~~'(n} 22 "",..",....""..,......,...... "......"..,....',..,..,'......, """"""""""""""""" """,'.""".."",.".""." "".,...",.,.......,..."""", g~pm::::(I) 2438--2460 ,..,......,....,.. , ,..'.. .. ,.. ..,.........., , .., ..".. ....,....,..,.. ".., , , ,.. ............, '..,'.. '..", " ..,........,.., ..' , .. " , "RrUñ~1¥l;jt1'1QIQgy , Shale Shale/Coal Coal Shale 2200--2400 2188--2200 200 12 2166--2186 2040--2130 20 90 CL-30 CL-31 CL-32 CL-33 CL-34 CL-35 CL-36 Shale/Coal Shale/Coal Shale Coal 1957 --1983 1668--1682 1660--1668 26 14 8 14 Coal Shale 1476--1490 1443--1476 33 22 1,293 Shale 1362--1384 Minimum Total Footage ~, ,'----'. 4-5 ,~, 5.0 WEll lOGS Well logs for the West McArthur River 0-1 well are provided in the pocket at the end of this application. Correlation of the proposed disposal zone and associated confining layer(s) in the West McArthur River Unit No, 1, 0-1, and Pan American West Foreland Unit No.2 wells is presented in Section 4.0, Geologic Information. ,_/'"'., "'----"', 5-1 ,r--., 6.0 CASING AND CEMENTING PROGRAM This section presents the casing and cementing program for the West McArthur River No. 0-1 well. Figure 6-1 shows a well schematic, and Table 6-1 gives the casing and cementing program summary. Casing design data and the Schlumberger Cement Advisor report are provided at the end of this Section. The 7" casing string has been tested to 1,000 psi following setting the packer. There was no pressure loss in 15 minutes. Prior to startup of injection operations, the casing annulus will be tested to 1,500 psi for 30 minutes in accordance with 20 AAC 25.030 (g). ~, ~, 6-1 ,~, 131' RKB ~ ( 100' BGL ) ~ 13 3/8" conductor, drilled and driven 1364' RKB ..11IIIIIIII ( 1333' BGL ) ~ 9 5/8" surface, cemented to surface , Tubing: 2 7/8", 6.5#, N-80, 8R, EUE /""", xx TIW Retrievable Packer Set @ 4197' Tubing Tail @ 4203.35 - Perforations 12HPF 4289' - 4351' 4500' RKB ~ ( 4469' BGL ) ~ 7" 29# P-110, S-95, N-80. combination string cemented to 1400 ft. r--- &at ENSR CONSULTING & ENGINEERING DRAWING: SCHEI.IDIA DRAWN: Jl/SR e/sc: 1 =1 DISK: D/563 DATE: 03/01/93 CHECK: JIA FIGURE 6-1 WEST McARTHUR RIVER WELL D-1 SCHEMATIC DIAGRAM STEWART PETROLEUM CO. WEST McARTHUR RIVER UNIT PROJECT 6397-003-400 6-2 ') ') TABLE 6-1 CASING AND CEMENTING PROGRAM - SUMMARY STEWART PETROLEUM WEST McARTHUR RIVER NO. D-1 Hole Casing Casing Depth, Depth @ Float Cement Slurry Size Size Description Shoe (RKB) Top Length Equipment Class Wt. 12-1/48 9-5/88 43.5 Ib, L-80, LTC 1,364 MD 0 1,364 F.C. G 12,0-12.5 (1,364 TVD) F,S. 8-1/28 7' 291b, P-110, LTC S-95, N-80 m ~ 4,500 MD (4,500 TVD) 0 4,500' F.C, F.S, G 15,0 - 16.0 ) Notes Used stab-in float collar and float shoe and cement to surface. Used calcium chloride (CaCI2) to accelerate cement and provide a 2,5 hour thickening time. Used top and bottom wiper plugs. Calculated cement volume plus 15% for 2,000 ft fillup above shoe. Used calcium chloride (CaCI2) to accelerate cement and provide a 4 hour thickening time, Casing Design Data is shown on the following pages. For the 78 casing string, N-80 data is provided as this is the lowest grade for the 78 string. 9-5/81 SURFACE CASING DESIGN DATA OPERATOR: STEWART PETROLEUM COMPANY DATE: ------------------------------------------ ?ASE: WEST McARTHUR RIVER UNIT NO. D1 FIELD: WEST McARTHUR RIVER -------------------- ---------------------------------------- 30-DEC-92 ------------------------- b.ciC. 16 TWP. 8N RNG. 14W COUNTY: KENAI ------ ------ ------ -------------------- STATE: ALASKA -------- SURFACE CASING CASING DESIGN DATA ------------------------------------------------------------------------------- ------------------------------------------------------------------------------- ------------------------------------------------------------------------------- ------------------------------------------------------------------------------- DESIGN CODE: 1 CASING STRING DESIGN CODE............................ = ***********SURFACE*********** 1 DESIGN FACTORS: 2 BURST DESIGN FACTOR.................................. = 1.100 3 COLLAPSE DESIGN FACTOR............................... = 1.100 4 TENSION DESIGN FACTOR................................ = 1.600 5 OVERPULL IN EXCESS OF THE STRING WEIGHT.........(LBS) = 100000.000 CASING BURST DESIGN DATA: 7 FRACTURE GRADIENT AT THE CASING SHOE + YOUR SAFETY FACTOR.............................. (PPG) = 8 GAS GRADIENT................................. (PSIjFT) = ,~WEIGHT OF BACKUP FLUID.......................... (PPG) = CASING COLLAPSE DESIGN DATA: 11 MUD WEIGHT CASING IS SET IN.....................(PPG) = 12 TOP OF CEMENT.................................... (FT) = 13 WEIGHT OF CEMENT................................ (PPG) = 14 WEIGHT OF COLLAPSE BACKUP FLUID................. (PPG) = CASING DESIGN DATA: 15 CASING SIZE, O.D.................................(IN) = 16 CASING (MIN. ACCEPTABLE) DRIFT DIAMETER.......... (IN) = 17 SETTING DEPTH.................................... (FT) = 18 MINIMUM SECTION LENGTH........................... (FT) = CALCULATION CONTROL DATA: 24 UPGRADE BURST FOR TENSION ...............(O=YES;l=NO) = 25 UPGRADE COLLAPSE FOR COMPRESSION ........(O=YES;l=NO) = 26 CONSIDER EFFECT OF BOUYANCY ON TENSION... (O=YES,l=NO) = 27 MAXIMUM LOAD;MAXIMUM STRAIN ENERGY.. (O=LOAD;l=STRAIN) = 12.500 .115 9.000 9.000 .000 12.000 .000 9.625 8.500 1350.000 .000 0 0 0 0 CASING TABLE NAME: 28 CURRENTLY SELECTED CASING TABLE............(CAS.BIN) = C:CAS.BIN ------------------------------------------------------------------------------- ------------------------------------------------------------------------------- "r-.. 9-5/8" SURFACE CASING DESIGN OPERATOR: STEWART PETROLEUM COMPANY DATE: 30-DEC-92 ------------------------------------------ -------------------- ~-ASE : WEST McARTHUR RIVER UNIT NO. D1 FIELD: WEST McARTHUR RIVER ---------------------------------------- ------------------------- ~l!.C. 16 TWP. 8N RNG. 14W COUNTY: KENAI STATE: ALASKA ------ ------ ------ -------------------- -------- SURFACE CASING ------------------------------------------------------------------------------- ------------------------------------------------------------------------------- CASING DESIGN 9.625 ------------------------------------------------------------------------------- ------------------------------------------------------------------------------- DEPTH (FT) LENGTH (FT) WEIGHT (LB/FT) GRADE JOINT PRICE ( $/FT) .0 1350.0 43.50 L-80 LTC 30.27 STRING COST = $ 40865. STRING WEIGHT = ** INTERNAL YIELD UPGRADED FOR TENSION ** ** COLLAPSE LOAD UPGRADED FOR COMPRESSION ** ** FORMULA USED: MAXIMUM LOAD THEORY ** 58725. LBS ------------------------------------------------------------------------------- ------------------------------------------------------------------------------- BURST ------------------------------------------------------------------------------- ------------------------------------------------------------------------------- PIPE IN TENSION NOT IN TENSION --------------- -------------- PIPE BURST PIPE DESIGN PIPE DESIGN :~--, DEPTH WEIGHT/GRADE/JOINT LOAD BURST FACTOR BURST FACTOR (FT) (PSI) (PSI) (PSI) .0 43.50/L-80 /LTC 721. 6461. 8.96 6330. 8.78 1350.0 43.50/L-80 /LTC 245. 6300. 25.67 6330. 25.79 ------------------------------------------------------------------------------- ------------------------------------------------------------------------------- COLLAPSE ------------------------------------------------------------------------------- ------------------------------------------------------------------------------- PIPE IN TENSION --------------- PIPE COLLAPSE PIPE DESIGN DEPTH WEIGHT/GRADE/JOINT LOAD COLLAPSE FACTOR (FT) (PSI) (PSI) .0 43.50/L-80 /LTC o. 3726. 1350.0 43.50/L-80 /LTC 841. 3828. 4.55 NOT IN TENSION -------------- PIPE COLLAPSE (PSI) DESIGN FACTOR 3810. 3810. 4.53 ------------------------------------------------------------------------------- ------------------------------------------------------------------------------- TENSION =============================================================================== PIPE TENSION JOINT/BODY TENSION DEPTH WEIGHT/GRADE/JOINT LOAD STRENGTH DESIGN FACTOR (FT) (1000 LBS) (1000 LBS) "--'-, 43. 50/L-80 .0 /LTC 48.2 825.0 17.13 1350.0 43.50/L-80 /LTC -10.6 825.0 -78.07 =============================================================================== 9-5/811 SURFACE CASING BURST PRESSURE VS. DEPTH OPERATOR: STEWART PETROLEUM COMPANY DATE: 30-DEC-92 ------------------------------------------ -------------------- f~ASE : WEST McARTHUR RIVER UNIT NO. D1 FIELD: WEST McARTHUR RIVER ---------------------------------------- ------------------------- ú,¡.;,C. 16 TWP. 8N RNG. 14W COUNTY: KENAI STATE: ALASKA ------ ------ ------ -------------------- -------- SURFACE CASING BURST PRESSURE VS. DEPTH 0 +----+-*--+----+----+----+----+----+----+----+----+----+----+---++----+ ! * + ! ! * + ! ! * + ! ! * + ! 500 + * + + ! * + ! ! * + ! ! * + ! ! * + ! 1000 + * + + ! * + ! ! * + ! ! * + ! ! ! 1500 + ! ! .r---. ! ; , ! 2000 + ! ! ! ! + ! ! ! ! + ! ! ! ! 2500 + ! ! ! ! + ! ! ! ! 3000 + ! ! ! ! + ! ! ! ! + ! ! ! ! 3500 + ! ! ! ! 4000 +----+----+----+----+----+----+----+----+----+----+----+----+----+----+ 0 1000 2000 3000 4000 5000 6000 7000 ,.r--. BURST DESIGN LINE PIPE BURST (PSI) (PSI) * + 9-5/8" SURFACE CASING COLLAPSE PRESSURE VS. DEPTH OPERATOR: STEWART PETROLEUM COMPANY DATE: 30-DEC-92 ------------------------------------------ -------------------- ~SE: WEST McARTHUR RIVER UNIT NO. Dl FIELD: WEST McARTHUR RIVER ---------------------------------------- ------------------------- ù~c. 16 TWP. aN RNG. 14W COUNTY: KENAI STATE: ALASKA ------ ------ ------ -------------------- -------- SURFACE CASING COLLAPSE PRESSURE VS. DEPTH 0 *----+----+----+----+----+----+----+-+--+----+----+----+----+----+----+ * + ! 1* + 1 1 * + 1 1 * + 1 500 + * + + 1 * + ! 1 * + 1 1 * + 1 1 * + 1 1000 + * + + 1 * + 1 1 * + 1 1 * + 1 1 1 1500 + 1 1 ./-" 1 1 2000 + 1 1 1 1 + 1 1 1 1 + ! 1 1 1 2500 + 1 1 1 1 + ! ! 1 ! + 1 1 1 1 3000 + ! 1 1 1 3500 + 1 ! 1 1 + ! ! ! 1 4000 +----+----+----+----+----+----+----+----+----+----+----+----+----+----+ 0 1000 2000 3000 4000 5000 6000 7000 ..r--- COLLAPSE DESIGN LINE (PSI) PIPE COLLAPSE (PSI) * + 9-5/811 SURFACE CASING TENSION VS. DEPTH OPERATOR: STEWART PETROLEUM COMPANY DATE: 30-DEC-92 ------------------------------------------ -------------------- ,~SE: WEST McARTHUR RIVER UNIT NO. D1 FIELD: WEST McARTHUR RIVER ---------------------------------------- ------------------------- b.L:.oC. 16 TWP. 8N RNG. 14W COUNTY: KENAI STATE: ALASKA ------ ------ ------ -------------------- -------- SURFACE CASING TENSION VS. DEPTH 0 +----*----+----+----+----+----+----+----++---+----+----+----+----+----+ ! * + ! ! * + ! ! * + ! ! * + ! 500 + * + + ! * + ! ! * + ! ! * + ! ! * + ! 1000 + * + + ! * + ! ! * + ! ! * + ! ! ! 1500 + ! ! ~.. ! ! + ! ! ! ! 2000 + ! ! ! ! 2500 + ! ! ! ! + ! ! ! ! + ! ! ! ! 3000 + ! ! ! ! + ! ! ! ! 3500 + + ! ! ! ! ! ! ! ! 4000 +----+----+----+----+----+----+----+----+----+----+----+----+----+----+ 0 200 400 600 800 1000 1200 1400 ~, TENSION DESIGN LINE (1000 LBS) JOINT/BODY STRENGTH (1000 LBS) * + 7" PRODUCTION CASING DESIGN DATA r", OPERATOR: STEWART PETROLEUM COMPANY DATE: WEST McARTHUR RIVER STATE: ALASKA ------------------------------------------ LEASE: WEST McARTHUR RIVER UNIT NO. D1 FIELD: ------------------------- -------- , ---------------------------------------- SEC. 16 TWP. 8N COUNTY: KENAI -------------------- RNG. 14W ------ ------ ------ 22-DEC-92 -------------------- PRODUCTION CASING =================------================- ------ --=============--------- CASING DESIGN DATA --================================= =================------============== DESIGN CODE: 1 CASING STRING DESIGN CODE............................ = *********PRODUCTION********** 5 DESIGN FACTORS: 2 BURST DESIGN FACTOR.................................. = 1.000 3 COLLAPSE DESIGN FACTOR............................... = 1.000 4 TENSION DESIGN FACTOR................................ = 1.600 5 OVERPULL IN EXCESS OF THE STRING WEIGHT.........(LBS) = 100000.000 CASING BURST DESIGN DATA: 6 SHUTIN BOTTOMHOLE PRESSURE......................(PSI) = 9 PACKER FLUID WEIGHT........ . . . . . . . . . . . . . . . . . . . . . (PPG) = 10 WEIGHT OF BACKUP FLUID..........................(PPG) = ~ CASING COLLAPSE DESIGN DATA: 11 MUD WEIGHT CASING IS SET IN.....................(PPG) = 12 TOP OF CEMENT....................................(FT) = 13 WEIGHT OF CEMENT................................ (PPG) = 14 WEIGHT OF COLLAPSE BACKUP FLUID.................(PPG) = CASING DESIGN DATA: 15 CASING SIZE, O. D. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (IN) = 16 CASING (MIN. ACCEPTABLE) DRIFT DIAMETER..........(IN) = 17 SETTING DEPTH.................................... (FT) = 18 MINIMUM SECTION LENGTH........................... (FT) = CALCULATION CONTROL DATA: 24 UPGRADE BURST FOR TENSION ...............(O=YES¡l=NO) = 25 UPGRADE COLLAPSE FOR COMPRESSION ........(O=YES;l=NO) = 26 CONSIDER EFFECT OF BOUYANCY ON TENSION... (O=YES,l=NO) = 27 MAXIMUM LOAD ¡MAXIMUM STRAIN ENERGY.. (O=LOAD¡l=STRAIN) = 2400.000 8.500 8.500 10.000 .000 15.500 .000 7.000 6.000 4000.000 .000 0 0 0 0 CASING TABLE NAME: 28 CURRENTLY SELECTED CASING TABLE............(CAS.BIN) = C:CAS.BIN ========================================------===========================------ ¡---- . 7" PRODUCTION CASING DESIGN OPERATOR: STEWART PETROLEUM COMPANY DATE: 22-DEC-92 ------------------------------------------ -------------------- LEASE: WEST McARTHUR RIVER UNIT NO. D1 FIELD: WEST McARTHUR RIVER ---------------------------------------- ------------------------- SEC. 16 TWP. 8N RNG. 14W COUNTY: KENAI STATE: ALASKA ------ ------ ------ -------------------- -------- PRODUCTION CASING ----------------------------------------------------- ------------- ----------------------------------------------------------------------- CASING DESIGN 7.000 ------==============================================================----------- DEPTH (FT) LENGTH (FT) WEIGHT (LB/FT) GRADE JOINT PRICE ($/FT) .0 4000.0 29.00 N-80 LTC 17.27 STRING COST = $ 69080. STRING WEIGHT = ** INTERNAL YIELD UPGRADED FOR TENSION ** ** COLLAPSE LOAD UPGRADED FOR COMPRESSION ** ** FORMULA USED: MAXIMUM LOAD THEORY ** 116000. LBS =============================================================================== BURST ====================================================================-------==== :/"'-'" PIPE IN TENSION NOT IN TENSION --------------- -------------- PIPE BURST PIPE DESIGN PIPE DESIGN DEPTH WEIGHT/GRADE/JOINT LOAD BURST FACTOR BURST FACTOR (FT) (PSI) (PSI) (PSI) .0 29.00/N-80 /LTC 2400. 8595. 3.58 8160. 3.40 4000.0 29.00/N-80 /LTC 2400. 8010. 3.34 8160. 3.40 =============================================================================== COLLAPSE ====================================================================--- PIPE IN TENSION --------------- PIPE COLLAPSE PIPE DESIGN DEPTH WEIGHT/GRADE/JOINT LOAD COLLAPSE FACTOR (FT) (PSI) (PSI) .0 29.00/N-80 /LTC o. 6574. 4000.0 29.00/N-80 /LTC 3220. 7142. 2.22 NOT IN TENSION -------------- PIPE COLLAPSE (PSI) DESIGN FACTOR 7020. 7020. 2.18 ------------------------------------------------------------------------------- ------------------------------------------------------------------------------- TENSION =============================================================================== PIPE TENSION JOINT/BODY TENSION DEPTH WEIGHT/GRADE/JOINT LOAD STRENGTH DESIGN FACTOR -~" (FT) (1000 LBS) (1000 LBS) / .0 29.00/N-80 /LTC 88.8 597.0 6.72 4000.0 29.00/N-80 /LTC -27.2 597.0 -21. 94 -------================================================================-------- 7" PRODUCTION CASING BURST PRESSURE VS. DEPTH r--,- OPERATOR: STEWART PETROLEUM COMPANY DATE: 22-DEC-92 ------------------------------------------ -------------------- LEASE: WEST McARTHUR RIVER UNIT NO. D1 FIELD: WEST McARTHUR RIVER ---------------------------------------- ------------------------- SEC. 16 TWP. 8N RNG. 14W COUNTY: KENAI STATE: ALASKA ------ ------ ------ -------------------- -------- PRODUCTION CASING r--, BURST PRESSURE VS. DEPTH 0 +----+----+---*+----+----+----+----+----+----+----+----+----+----+----+ 1 * + 1* + 1 * + 1 * + 1000 + * + 1 * + 1 * + 1 * + 1 * + 2000 + * + 1 * + 1 * + 1 * + 1 * + 3000 + * + 1 * + 1 * + 1 * + 1 * + 4000 + * + 1 ! ! ! 1 1 1 1 5000 + 1 1 1 ! + ! 1 ! ! 6000 + ! 1 1 1 + ! ! 1 ! 7000 + + 1 1 1 ! 1 1 1 1 8000 +----+----+----+----+----+----+----+----+----+----+----+----+----+----+ 1000 2000 3000 4000 5000 6000 7000 8000 ..r--', BURST DESIGN LINE PIPE BURST (PSI) (PSI) * + 7" PRODUCTION CASING COLlAPSE PRESSURE VS. DEPTH ~--- OPERATOR: STEWART PETROLEUM COMPANY DATE: 22-DEC-92 ------------------------------------------ -------------------- LEASE: WEST McARTHUR RIVER UNIT NO. D1 FIELD: WEST McARTHUR RIVER ---------------------------------------- ------------------------- SEC. 16 TWP.8N RNG. 14W COUNTY: KENAI STATE: ALAS KA ------ ------ ------ -------------------- -------- PRODUCTION CASING :.r---'" COLLAPSE PRESSURE VS. DEPTH 0 *----+----+----+----+----+----+-+--+----+----+----+----+----+----+----+ * + ! ! * + ! ! * + ! ! * + ! 1000 + * + + ! * + ! ! * + ! ! * + ! ! * + ! 2000 + * + + ! * + ! ! * + ! ! * + ! ! * + ! 3000 + * + + ! * + ! ! * + ! * + ! * + 4000 + * + ! ! ! f + ! ! ! ! 5000 + ! ! ! ! + ! ! ! ! 6000 + ! ! ! ! + ! ! ! ! 7000 + + ! ! ! ! ! ! ! ! 8000 +----+----+----+----+----+----+----+----+----+----+----+----+----+----+ 0 2000 4000 6000 8000 10000 12000 14000 ".,-.... COLLAPSE DESIGN LINE (PSI) PIPE COLLAPSE (PSI) * + 7" PRODUCTION CASING TENSION VS. DEPTH ¡--. OPERATOR: STEWART PETROLEUM COMPANY DATE: 22-DEC-92 ------------------------------------------ -------------------- LEASE: WEST M~THUR RIVER UNIT NO. Dl FIELD: WEST McARTHUR RIVER ---------------------------------------- ------------------------- SEC. 16 TWP.8N RNG. l4W COUNTY: KENAI STATE: ALASKA ------ ------ ------ -------------------- -------- PRODUCTION CASING ~-.- TENSION VS. DEPTH 0 +----+----+---*+----+----+----+----+----+----+----+----+---++----+----+ ! * + ! ! * + ! ! * + ! ! * + ! 1000 + * + + ! * + ! ! * + ! ! * + ! ! * + ! 2000 + * + + ! * + ! ! * + ! ! * + ! ! * + ! 3000 + * + + ! * + ! ! * + ! ! * + ! ! * + ! 4000 + * + + ! ! ! ! ! ! ! ! 5000 + ! ! ! ! + ! ! ! ! 6000 + + ! ! ! ! ! ! ! ! 7000 + + ! ! ! ! ! ! ! ! 8000 +----+----+----+----+----+----+----+----+----+----+----+----+----+----+ 0 100 200 300 400 500 600 700 ,r--. , TENSION DESIGN LINE (1000 LBS) JOINT/BODY STRENGTH (1000 LBS) * + I~' CEMENT ADVISOR Company: STEWART PETROLEUM COMPANY ,~, Field: West McArthur River Well: West McArthur River No. D-1 Logging Date: January 25, 1993 r' -- ~- January 25, 1993 Dear Sir: I believe you will find this report and enclosed color logs useful in evaluating the cement in this well. The interpretation contained in this report is the result of my application of the known tool responses for the Cement Bond Tool (CBT) and the Cement Evaluation Tool (CET) to your well. I have included a copy of the log in the back cover, as well as, a header for use with the log sections in the report. The color log contained within the report is new and deserves a brief description. The Variable Density Log (VDL) is much like the field VDL, but the amplitude of the received signal is now presented in color. Dark green and white represent a wave of high amplitude; the white representing the trough, and the green the peak. As the amplitude decreases, the green becomes blue, and the white becomes orange. Violet represents an amplitude of zero. The attenuations, Near and Discriminated, are identical to those on the CBT log. :~'" The color CET map is very different from the map presented in the field. Six different colors are used to represent specific acoustic impedance bands. These bands cover the following: Red: Yellow: Blue: Green: Brown: Black: Free gas behind pipe. Typically gas cut cement. Water or drilling mud behind pipe. Mud contaminated cement. Cement slurry, no compressive strength, 500 psi compressive strength cement. Again, I believe you will find this report useful. Should you require further explanation on any detail, feel free to contact me or another Schlumberger representative. ~~ Brian Schwanitz Schlumberger Well Services :~" ,~--- DETAILED INTERPRETATION 7" 29# LINER (Cont.) 1,400' . 2,400' GOOD CEMENT The major defect in this cement job is a channel from 1,426' - 1,510. It covers about 40% of the pipe based in the CET image, but is sealed both at the top, from 1,384' - 1,404' and at the bottom. The CBT confirms the channel with a strong casing signal, showing casing collar ring, and yet, giving a formation signal, indicating good bond on one side of the pipe. ~-" ,~'. DETAILED INTERPRETATION 7" 29# LINER (Cont.) 2,400' - 3,400' EX CELLENT CEMENT Two voids exist: a large one from 2,454' - 2,490', and a small one at 2,560'. The large one looks like mud cut cement due to poor displacement. However, the hydraulic seal is intact - no fluids will communicate.' 7'-, r"', ,~- DETAILED INTERPRET A TION 7" 29# LINER NOTE: These logs were run with 1,000 psi surface pressure. 3,400' - 4,400' EXCELLENT CEMENT The only defect in the cement sheath is at the shoe which looks slightly wet on the CET from 4,380' - 4,400'. Compressive strengths range from high peaks of 6,000 psi to low peaks of 1,000 psi, with an average strength of 3,700 psi. ,r'- /,.,-...." '-.. I \ :~. ,,-..., CEMENT EV ALUA TION SUMMARY CHANNELS: The only continuous channel in the 7" cement job is from 1,426' - 1,510'. This channel appears to cover 40% of the casing, but is sealed àt the top (at the base of the 9 5/8" casing) and at the bottom of the channel. GAS CUT CEMENT: No gas cut cement or free gas is present in the liner job. LINER CEMENT QUALITY: The overall quality of the liner cement is excellent. Aside from the one channel (noted above),there are a few voids in the sheath between 2,090' - 2,500'. The average compressive strength is 3,700 psi. I LINE LAP CEMENT QUALITY: The liner lap has poor cement. It appears to be either contaminated or still green with the consistency of a heavy drilling mud.. r-. 7.0 INJECTION FLUID All waste fluids to be injected will be generated by drilling and production operations at the West McArthur River Unit. These injection fluids will include the following: . Waste drilling fluids . Completion fluids . Diluted drilling fluids . Slurried drill cuttings (with slurry makeup water) . Waste cement (watered down) . Produced Water /'-"" It is estimated that up to 6,000 bbl per day of fluid may be injected during periods of maximum injection activity. Average anticipated injection rates will be about 2,000 to 3,000 bbl per day during drilling òperations or during drill cuttings grinding and disposal, operations. The total yearly volume of injected fluids will be dependent on the duration of future drilling operations, but is anticipated to be about 350,000 bbl per year through 1995. The radius of invasion around the wellbore is given by R = CV j1thrp)Va where R¡ = radius of invasion (ft) V = volume injected (fe) h = height of reservoir (ft) rp = porosity (%) Assuming 350,000 bbl (5.9 x 106 ft3) of fluids are injected per year, the radius of invasion would be 571 ft after 10 years of injection activity. r" 7-1 ,~ The fluids listed above will generally be discharged to the facility reserve pit prior to injection disposal. The resulting mixture will consist of the individual components identified in Table 7-1 and 7-2. The listed fluids are classified as non-hazardous by the U.S. Environmental Protection Agency and are suitable for injection into Class II wells. ,~. /'"'" 7-2 '-"-""'. TABLE 7-1 Waste Drilling Fluid Composition Material Percent by Weight Fresh Water 80-90 3-4 Bentonite Barite Potassium Chloride (KCI) Polyanionic Cellulose 2-20 0-5 Potassium Hydroxide Caustic Soda 0.0.7 0-0.1 "'---"'- PHPA Polymer Sodium Nitrate 0-1.1 0-0.5 Lime 0-0.02 0.5 Caustic Soda Soda Ash 0-1 0-0.5 Sodium Bicarbonite Chrome free Lignosulfonate 0-1 0-2 Drilled Solids/Cuttings Cement 10-20 0-5 Total 100.0 .r-',., 7-3 ,~. TABLE 7-2 Completion Fluid Composition Material Fresh Water Percent by Weight 75 24 Potassium Chloride Corrosion Inhibitor 0.5 0.5 100.0 Defoamer Total -~--, .r----, 7-4 r-.. 8.0 INJECTION PRESSURE The average surface injection pressure is estimated to be 800 to 1,000 psi at a depth of 4,289 ft, The maximum anticipated surface injection pressure will be approximately 1,115 psi at the estimated formation fracture pressure (3,345 psi). These figures are based on a fracture gradient of 15.0 ppg at a depth of 4,289 ft and 10.0 ppg injection fluid in the tubing string. The maximum surface injection pressure will be limited to the working pressure of the casing head which is 3,000 psi. /"-. :r---. 8-1 ¡-, 9.0 FRACTURE INFORMATION The proposed injection formation may be fractured periodically to enhance the ability of the formation to accept fluid. The induced fractures will, however, be localized near the wellbore and confined to the injection zone. The proposed injection formation is confined above and below by a series of tight interbedded claystones, siltstones, and coals which are known to be effective confining layers and barriers to fracture propagation in the Cook Inlet Basin. In addition, the shales (claystone, siltstone, and mudstone) are plastic in nature which augments their ability to provide containment. Descriptions of the confining layers and the proposed injection zone are provided in the Geological Information section of this document. The injection zone and associated confining beds are laterally continuous in the area based on correlation of well logs. The well logs indicate that the proposed injection zone and associated confining beds were encountered in the surrounding West McArthur River Unit No.1 and Pan American West Foreland Unit No.2 wells (see Geological Information section). -^'"- The proposed injection zone is 60 ft thick, consisting of porous cemented sandstone with silt and coal interbeds. This unit is highly porous and permeable based on well log analysis, The calculated porosity and permeability (from well logs) of this zone in the West McArthur River No. 0-1 well are 32% and 1,600 md, respectively. In highly porous and permeable units, induced fractures are difficult to sustain and only propagate limited distances from the wellbore. Any fractures that are induced in the formation will tend to propagate laterally within in the disposal zone rather than vertically into the impermeable confining layers above and below the disposal zone. A fracture model was used on the injection zone to confirm that the induced fractures would not propagate beyond the injection zone (see attached BJ Services correspondence), The fracture model was the MFRAC " by Meyer and Associates, Inc. This model is a three-dimensional hydraulic fracturing simulator. When possible, existing reservoir data was input to the model. Otherwise, rock properties were estimated based on average values for similar lithologies under analogous subsurface conditions. Input data is identified in the Formation Data section of the model. N------'- The fracture model was run at a pump rate of 5 barrels per minute (bpm) and maximum surface pressure of 5,000 psi. Five bpm is anticipated to be the maximum injection rate of fluids, and 5,000 psi is 2,000 psi beyond the working surface pressure limit of the wellhead (3,000 psi). 9-1 .-""---"-, Even under these worst case (impossible) injection conditions, the model demonstrates that the induced fractures would be confined to the injection zone. The confining shale zones immediately above and below the injection zone are depicted in Section 4.0, Geologic Information. Prior to commencing injection operations in the West McArthur River No. 0-1 well, a stepped-rate pump test will be performed to determine the formation fracture gradient and optimum injection rate. After disposal operations commence localized fracturing may occur when injection pressures approach the formation fracture pressure as solids accumulate near the well bore. If fracturing is induced, the fractures should be confined to the injection zone immediately surrounding the well bore. ~- /.r---, , 9-2 Wj /'- Please Reply: 6927 Old Seward Hwy" Ste, 201 Anchorage. AI{ 99518 (907) 349-6518 February 22, 1993 Mr. Jesse Mohrbacher ENSR Consulting & Engineering 4640 Business Park Blvd. Bldg D Anchorage, AK 99567 Dear Jesse: Attached is a ftacturing simulator run for the Stewart Petroleum Company West McArthur River No. D-1 Well. The injection zone is identified as the perforated sandstone ftom 4,289' to 4,351', ~--'- The model was setup to pump 1 MM gallons of a Newtonian fluid at a rate of 5 BPM carrying 5 ppg of 100 mesh material, To raise the pressure above the operational limits, a 100,000 gallon stage offluid carrying 20/40 mesh propp ant was added. This stage creates a pressure out (screen out) situation with surface pressure exceeding 5,000 psi. At this condition the ftac height is still contained by the confining shales above and below the injection zone. The boundary conditions for the well, were average for common shale boundaries accepted by the industry, these conditions are stated in the Formation Data section of the Fracture Model. If you should have any questions regarding this information please feel free to call me here at 349-6518, Sincerely, ~^'-_. ~.,1;fi.-,:',-, ' ----=-. ,~t;~ District Engineer BJ Services Company. U.S.A. . 5500 Northwest Central Drive. Houston. Texas 77092 . 713-462-4239 1', " Date: 02-19-1993 Time: 11:11:3 MFRAC-II A THREE-DIMENSIONAL HYDRAULIC FRACTURING SIMULATOR MFRAC-II is a trademark belonging to MEYER & ASSOCIATES,lne. --------------------------------------------------------------------- COPYRIGHT (C) 1985 - 1992, MEYER & ASSOC.,lne. - all rights reserve R.D.1 Box 458F, Natrona Heights, Pa. (U.S.A.) 15065 Intl. Corporate License «BJ Services », Tornball Serial #F3d.196, Date: 01-02-92 MFRAC-II Version 6.20 June 29, 1992 ******************** * ECHO INPUT DATA * ******************** >"'--- - , Stewart Petroleum Feb. 19, 1992 West Mcartheur Rive". P D-I RUN OPTIONS *********** IREAL = 0 NETPV = 0 IUNIT = 0 IGEOH = 3 ILGTH = 0 IZONE = 0 ILEAK = 0 IHEAT = 0 IFLBK = 0 ISAND = 1 IFRIC = 3 NITER = 40 IPRTS =999 O-DESIGN MODE.. 1-REPLAY MODE.. 2-REAL a-NO NET PV.... 1-NET PRESENT VALUE SET O-ENGLISH...... 1-METRIC....... a-PENNY........ 1-GDK..2-PKN... 3-THREE a-CALC. LGTH... 1-INPUT LENGTH. a-PAY LEAK-OFF. 1-MULTI-ZONE... LEAK-OF O-C=CONSTANT... 1-C=HARMONIC... 2-C=DYN a-NO HEAT...... 1-HEAT TRANSFER ....... a-NO BREAKER... 1-FLUID BREAKER WITH TI a-NO SAND...... 1-INPUT SCH.... 2-OUTPU a-NO FRIC...... 1,2-PW-LAW ilii 3,4-TBL # OF FRAC SOLN ITERATIONS (10 < NITER < PRINT SAND SOLN EVERY "IPRTS" STEP... /"--"- ILDOT = ISTBL = ITURB = IWALL = IRATE = ISNDL = IRAMP = ICONC = ISETl = 0 O-dL (+,-)..... 1 a-NO TABLE..... 0 O-LAMINAR FLOW. 0 a-SMOOTH WALL.. 0 O-RATE (b.c.).. 1 a-NO SND LINK.. 0 a-NO RAMP...... 0 O-LIQUID....... 0 Q-INPUT VEL.... 1-dL=O (q=O)... 2-dL/dt 1-STRESS TABLE. .(FILE1 1-LAMINAR/TURB. (Frac). 1-ROUGH WALL..& OVER-PR 1-BHP (b.c.)... ....... 1-LINK SAND and FRAC SO 1-RAMP SCHEDULE ....... 1-SLURRY....... .(MASSI 1-LOW..........2-MED. ICLOS = 0 O-NO CLOSE..... 1-PRES DECLINE. (FRAC C IPROD = 0 O-NO PROD...... 1-CONSTANT RATE 2-CONST ISOLN = 2 O-INTEGRAL SOL. 1-MIXED SOLN... 2-F.D. ISTOL = 1 O-GOOD......... 1-VERY GOOD.... 2-MACH. ~, - 1 - FORMATION DATA ************** YOUNG'S MODULUS RESERVOIR..... YOUNG'S MODULUS UPPER LAYER... YOUNG'S MODULUS LOWER LAYER... POISSON'S RATIO RESERVOIR..... POISSON'S RATIO UPPER LAYER... POISSON'S RATIO LOWER LAYER... MIN. HORIZONTAL STRESS RES.... FRACTURE TOUGHNESS RESERVOIR.. FRACTURE TOUGHNESS UPPER LAY.. FRACTURE TOUGHNESS LOWER LAY.. TOTAL PAY ZONE HEIGHT......... PERFORATION HEIGHT UPPER...... PERFORATION HEIGHT LOWER...... i""'---' LEAK-OFF COEF. & LAYER DATA *************************** 2.300E+06 psi 8.000E+06 psi 8.000E+06 psi .220 .250 .250 3345.0 psi 800.0 psi in^.5 1200.0 psi in^.5 1200.0 psi in^.5 62.00 ft 31.00 ft 31.00 ft ZONE LAYER LEAK-OFF NET PERM TOTAL CO LAYER THICKNESS HGHT RATIO LAYER HGHT LEAK-OF (ft) (-) (ft) (ft/nn^. -------- ---------- ---------- ---------- -------- -------- ---------- ---------- ---------- -------- Pay Zone 62.00 1.0000 62.00 1.000E- RESERVOIR LEAK-OFF DATA *********************** ZONE AVERAGE TOTAL COMP RESERVOIR RESERVOIR LAYER RES. PRES. Ct PERM. POROSITY (psi) (1/psi) (mcI) (-) -------- ---------- ---------- --------- --------- -------- ---------- ---------- --------- --------- Pay Zone 2000.00 2.000E-06 1000.0000 .3200 STRESS TABLE ************ ',/"---', DHU (ft) DSU (psi) / DHL (ft) DSL (psi) ---------------------- ---------------------- .000 5.000 100.000 .0 1500.0 1500.0 / I I .000 5.000 100.000 .0 1000.0 1000.0 TREATMENT DATA ~" ************** INJECTION RATE C2-WINGS CONST) NP - FLOW BEHAVIOR INDEX...... KP - CONSISTENCY INDEX........ FRAC FLUID SPECIFIC GRAVITY... PROPPANT DATA - 2 - ************* NO. SAND LAYERS FOR BRIDGING.. MIN. CONC./AREA FOR PROP. LGTH CLOSURE PRESSURE ON PROPPANT.. SAND SCHEDULING INPUT DATA ************************** /---"', VOL gal l CONS1 CONS2 lb/gal.l lb/gal.l STAGE NO. 5.000 bpm 1.0000 1.000E-03 lbf-s^np 1.020E+00 - 2.000E+00 - 1.000E-03 lbm/ft^2 3.000E+03 psi D.F. VEL ft/nn ======================================================= 1 2 3 .00 10.00 5.00 10000.D .1000E+07 100000.0 .00 10.00 5.00 SAND SCHEDULING SUMMARY TABLE ***************************** .010 .500 .500 1.00 1.00 1.00 STAGE VOLUMES TOTAL VOLUMES AVERAGE SLURRY / LIQUID SLURRY / LIQUID SLURRY 1 gal s. 1 gal l. gal s. / gal l. lbm/gal 1 ===== =========1========= =========1========= ========/ 1 10000.0/ 10000.0 10000.0/ 10000.0 .000/ 2 .145E+07/ .100E+07 .146E+07 / .101E+07 6.885/ 3 .123E+06/ .100E+06 .159E+07 1 .111E+07 4.077 / STAGE NO. WELLBORE HYDRAULICS DATA ************************ ;/"""-"" MODE 1-TUBING 2-ANNULUS 3-BOTH TOTAL WELL PIPE LENGTH........ WELL DEPTH TO PERFORATIONS.... TUBING DIAMETER ...CI.D.)..... FRICTIONAL PRES. LOSS RATIO... PERFORATION DIAMETER.......... TOTAL NO. OF PERFORATIONS..... 1 4250.00 ft 4300.00 ft 'C'. 2.4400 ii'h 1.0000 -- .6500 in 100.0 -- TUBING VOLUME TO PERFS........ 1032.4 gal r-.. PRESSURE LOSS VS RATE ********************* Sch# = 1 FLOY RATE PRESSURE LOSS (bbls/min) (psi/1000 ft) -------------------------- 1.00 2.00 4.00 8.00 25.00 90.00 - 3 - ********************************* * FRACTURE PROPAGATION SOLUTION * ********************************* ~- -. TIME VOLUME PRES_DPW LENGTH WDTH]AY WDTH_AVG WDTH_AVG emin) (gal s) (psi) (ft) y=0 (in) well(in) frac(in) ======== ========= ======== ======== ======== ======== ======== 162.550 34135.4 121.5 15.50 .0684 .0539 .0457 204.094 42859.7 125.1 18.77 .0713 .0561 .0476 253.535 53242.3 130.0 22.78 .0745 .0585 .0497 305.728 64202.9 134.5 26.95 .om .0606 .0515 357.473 75069.4 138.6 31.00 .0797 .0625 .0530 423.723 88981.9 143.4 35.63 .0825 .0646 .0545 562.546 118134.7 151.6 44.42 .0874 .0682 .0567 735.152 154381.8 160.6 54.64 .0928 .0722 .0591 932.795 195886.9 169.1 65.51 .0980 .0761 .0613 1138.699 239126.8 176.6 76.17 .1026 .0794 .0631 1343.907 282220.4 183.1 86.32 .1065 .0823 .0647 1513.561 317847.9 188.2 96.01 .1099 .0847 .0664 1706.133 358288.0 193.5 105.91 .1132 .0871 .0678 1894.324 397808.0 198.0 115.42 .1161 .0892 .0691 2095.740 440105.5 202.1 124.70 .1187 .0910 .0701 2294.250 481792.6 205.7 133.55 .1209 .0926 .0710 2489.665 522829.6 208.9 142.12 .1230 .0941 .0718 2683.058 563442.1 211.9 150.48 .1249 .0955 .0725 2874.982 603746.2 214.7 158.67 .1267 .0967 .0733 3065.687 643794.2 217.3 166.72 .1284 .0979 .0739 3255.341 683621.7 219.7 174.63 .1300 .0990 .0745 r--. 3444.093 723259.6 222.0 182.43 .1314 .1001 .0752 3632.090 762738.9 224.2 190.11 .1328 .1011 .0757 3819.461 802086.9 226.3 197.69 .1341 .1020 .0763 4006.320 841327.1 228.3 205.11 .1354 .1029 .0169 4192.758 880479.2 230.2 212.55 .1366 .1038 .0774 4378.853 919559.1 232.1 219.84 .1378 .1046 .0779 4564.667 958580.0 233.8 227.05 .1389 .1054 .0784 4750.250 997552.5 235.5 234.18 .1399 .1062 .0789 .493564E+04.1036E+07 237.2 241.22 .1410 .1069 .0794 ~, .512090E+04.1075E+07 238.7 248.19 .1420 .1076 .0798 I .530643E+04.1114E+07 240.3 255.08 .1429 .1083 .0803 .549213E+04.1153E+07 241.8 261.89 .1439 .1090 .0807 .567785E+04.1192E+07 243.2 268.62 .1448 .1097 .0811 .586350E+04.1231E+07 244.6 275.28 .1456 .1103 .0815 .604905E+04.1270E+07 245.9 281.87 .1465 .1109 .0819 .623426E+04.1309E+07 247.2 288.40 .1473 .1115 .0823 ,641913E+04.1348E+07 248.5 294.86 .1481 .1121 .0827 .660402E+04.1387E+07 249.8 301.27 .1489 .1126 .0830 .678887E+04.1426E+07 251.0 307.62 .1497 .1132 .0834 .697368E+04 .1464E+07 252.2 313.92 .1504 .1137 .0838 .715821E+04.1503E+07 253.3 320.16 .1511 .1142 .0841 .734231E+04.1542E+07 256.8 326.35 .1533 .1158 .0853 .754835E+04.1585E+07 3252.9 326.35 1.9417 1.4680 1.0800 -------------------------------------------------------------- Average Injection Rate (2-wings)=> Q = 5.00 bbl/min Equivalent Flow Behavior Index..=> np = 1.0000 - Equivalent Consistency Index....=> kp = 1.000E-03 lbf-s^np/ft^ - 4 - ~'- ******************************** * WELLBORE HYDRAULICS SOLUTION * ******************************** TIME INJ TIME SURF DP GRAVITY DP FRIC DP PERF (min) (min) (psi) (psi) (ps i) ************************************************************** 162.5496 167.4655 -2849.19 577.72 .07 204.0940 209.0100 -2849.19 577.72 .07 253.5348 258.4508 -2849.19 577.72 .07 305.7282 310.6442 -2849.19 577.72 .07 357.4731 362.3890 -2849.19 577.72 .07 423.7234 428.6393 -2849.19 577.72 .07 562.5463 567.4623 -2849.19 577.72 .07 735.1515 140.0675 -2849.19 577.72 .01 932.7948 937.7108 -2849.19 577.72 .07 1138.6988 1143.6147 -2849.19 577.72 .07 1343.9066 1348.8226 -2849.19 577.72 .07 1513.5612 1518.4m -2849.19 577.72 .07 1706.1334 1711.0494 -2849.19 577.72 .07 ,~-'- 1894.3238 1899.2397 -2849.19 577.72 .07 2095.7405 2100.6565 -2849.19 577.72 .07 2294.2503 2299.1662 -2849.19 577.72 .01 2489.6645 2494.5805 -2849.19 577.72 .01 2683.0577 2681.9736 -2849.19 577.72 .07 2874.9816 2879.8976 -2849.19 577.72 .07 3065.6865 3070.6025 -2849.19 577.72 .07 3255.3410 3260.2570 -2849.19 577.72 .07 3444.0933 3449.0093 -2849.19 577.72 .07 ~, 3632.0899 3637.0059 -2849.19 577.72 .07 3819.4611 3824.3771 -2849.19 577.72 .07 4006.3195 4011.2355 -2849.19 577.72 .07 4192.7579 4197.6738 -2849.19 577.72 .07 4378.8528 4383.7688 -2849.19 577.72 .07 4564.6665 4569.5825 -2849.19 577.72 .07 4750.2496 4755.1656 -2849.19 577.72 .07 4935.6424 4940.5583 -2849.19 577.72 .07 5120.8958 5125.8118 -2849.19 577.72 .07 5306.4284 5311.3444 -2849.19 577.72 .07 5492.1289 5497.0449 -2849.19 577.72 .07 5677.8474 5682.7634 -2849.19 577.72 .07 5863.5029 5868.4189 -2849.19 577.72 .07 6049.0539 6053.9698 -2849.19 577.72 .07 6234.2630 6239.1790 -2849.19 577.72 .07 6419.1317 6424.0477 -2849.19 577.72 .07 6604.0214 6608.9374 -2849.19 577.72 .07 6788.8739 6793.7899 -2849.19 577.72 .07 6973.6m 6978.5936 -2463.37 577.72 .06 7158.2090 7163.1249 -2463.37 577.72 .06 7342.3150 7347.2309 -2463.37 577.72 .06 7548.3472 7553.2632 -1902.95 577.72 .04 ******************************* r', * PROPPANT TRANSPORT SOLUTION * - 5 - ******************************* TlME_INJ (min) VOLUME DISTANCE WDTH_PAY EFFO CON_INLET CONL_EO (gal) (ft) (in) (-) (lb/gal l) (lb/gal ============================================================== NSH = 3 .7548E+04 .1585E+07 .00 1.6124 1.0000 5.000 36.25 .7490E+04.1573E+07 98.22 1.4554 .8000 5.000 36.25 .7432E+04.1561E+07 179.07 1.2516 .5965 5.000 36.25 .7373E+04.1548E+07 250.07 .9739 .3898 5.000 36.25 .7315E+04 .1536E+07 303.14 .6029 .1808 5.000 36.25 .7264E+04.1525E+07 326.35 .0000 .0000 5.000 .00 ~-. Fluid injected before time =7263.64 min is loss due to leak-of The volume of fluid to account for this loss is 1525363.6 gals Propped Length XLP = 303.14 ft Fracture Condo KFWF= 12566.60 md-ft Dim. Frec Cond FCD = .0415 r---, ~.. ~" Avg. Frac Perm KF = Avg. Con/Area CAREA= Prop. Vol. Fracture= Sch # Screen-out O-no 1-yes ----- ---------- ---------- 3 2 1 1 0 0 120.000 darcy 11.1764 lbmlft^2 sand itype # > 0 1.2092 fraction Proppant Displacement & Location Dist. from Well Screen-out Dist. (ft) to (ft) (ft) to (ft) =======-======= ========-======= .0. 326.4 .0 - 326.4 All fluid leaked-off:no propped sand All fluid leaked-off:no propped sand For a banking fluid, the Screen-out distance only represents the propped pack volume (distance). - 6 - r. 0 0 0 CO G-- !è --0 ~-~ 0 0 0 0 I> 0 I> - Q) 0 I> 0 S - 0 1>- 0 0 I> 0 0 I> CD . r-i - 0 I> - ~ 0 I> 0 0 I> 0 0 I> - o~ if] 0 I> LD ~ > - 0 I>.~ 0 ~ - 0 S 0 /'""""'. 0 I> - 0 "-'" G) 0 0 I> ~ Q) ~ 0 I> - 0 1>- S ~ 0 I> O.~ if] - 0 1>- 0 ~ 0 I> 0 if] 0 I> C'J Q) 0 1>- (f) Q) 0 I> 0 H Q) ~ 0 I> 0 ~ :J P-, 0.. (f) 0 I> 0 Q) (f) 0 I> C\2 Q) 0 ~ 0 1>- - 0.. ..c 0 I> E Q) 0 I> 0 u 0 - 0 0 0 1>- 0 -+-' -.- -+-' ~ 0 :J 0 I> ~ ..Q (f) 0 1>- 0 I> ~ ~ 0 6 8 ¿ 9 .g 17 £; 2 1 (£01 Tsd) d.1nSSd.1d ¿--- ,'" ". /--'" íJJ Q) F""-I . F=f ~ 0 ~ ~ !.r----'" Q) ~ ~ ~ u cD ~ ~ ...r---", 091 I 001 I' ~ I I ~ ~ , , '\ ì ~ ~ I I 09 0 09- (1J) 1q~1dH a - a OJ a - L() C\2 0 L() OJ I ' ~ ~ a 4-i - a '-'" C\2 ~ ~ oOJJ - L() ~ ...-iQ) ~ a - 0 ...-i 0 -L() a 001- 091- ~- Q) s . F==i ~ ,~.,'. if'1 > ~ ~ blJ- ~ Q) ~ 09£; ".r--,. I OOb 092 002 091 001 (1J) q1~Ud1 09 a a a co 0 0 - 0 ['- a a - 0 CD 0 0 ,....--. - 0 ~ LD.,.....j - S a "'-'" 0 -0 ~ Q) oS o.,.....j - o~ OJ a 0 -0 N 0 0 - 0 ~ 0 0 :~--'" 1 0.0 FORMATION FLUID The proposed injection zone was perforated by tubing conveyed guns with approximately 900 psi under-balance. After perforation, the backs urge was reverse circulated out of the hole in order to collect formation fluid samples for laboratory analysis and to clean out perforation debris. Samples were collected for laboratory analysis as follows: Base: The freshwater base fluid in the 2 7/8" x 7" casing annulus and water cushion makeup No.1: Sample from the mixture of water cushion and formation fluid (backsurge) No.2: Sample from the backsurge No.3-8: Additional samples from the mixture of formation fluids and base fluid used to reverse circulate out of the hole /",-". The analytical results for sample no. 2 indicate that the formation fluid contains at least 11,800 ppm total dissolved solids (TOS). This sample is believed to be the most representative of the formation fluids while the other samples have been diluted by mixing with the base fluid during the reverse circulation. A copy of the sample results are presented in the following pages. Well log calculations indicate a TOS value of 4,800 ppm for the proposed injection zone. The log calculated TOS employees the USEPA-approved Spontaneous Potential (SP) method (see attached Schlumberger Well Services letter). This method assumes a clean homogenous formation with uniform porosity and permeability. Experience has shown that the Tyonek formation is not 100% clean, but rather has highly varied characteristics due to the presence of silt and clay. For this reason, the actual TOS in the disposal zone is significantly higher than 4,800 ppm as determined by the SP method, The TOS value is 5,600 ppm when calculated by the alternate Resistivity-Porosity (RP) method. The nonexempt aquifers « 3,000 ppm TOS) were also determined by the SP method. This transition area occurs between 1,280 feet and 1,490 feet in the West McArthur River No. 0-1 well. The actual 3,000 ppm TOS aquifer transition may be deeper (lower) in the 0-1 well as the SP method tends to under-estimate the true TOS concentration in the aquifer. /.-' ~ - , 10-1 ~ SCHLUMBERGER WELL SERVICES 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 Telephone: (907) 562-2654 Fax: (907) 563-3309 "~- March 2, 1993 Jesse Mohrbacher ENSR Consulting and Engineering 4640 Business Park, Bldg D Anchorage, AK 99501 Dear Jesse, As you have requested, we are providing the following report on calculating total disolved solids (IDS) from well logs on the West McArthur River No. D-1. Note: the hole is esentially vertical. The SP Method: Usin~ Schlumberger's Charts SP-I. SP-2. and Gen-9. /.r-,-\ 1210' - 1270' SSP = -20 mv Rmf = 3.36 @ 68° F Tf = 68° F Rmfeq = 2,86 Rweq = 1.5 => (Rw - 5) IDS = 1,150 ppm 1500' - 1540' SSP = -40 mv Tf=71°F Rmf= 3.55 @ 71° F Rmfeq :;: 3.02 Rweq = 0.86 Rw = 1.6 IDS = 3,600 ppm 1900' - 1950' SSP = -40 mv Tf = 73°P Rmf= 3.46 @ 73°P Rmfeq = 0.86 Rw = 1.6 IDS = 3,500 ppm ,.r--.. A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION / ----- . 4289' - 4361' SSP = -30 mv Tf= 94° F Rmf= 2.74 @ 94° F Rmfeq = 2.33 Rweq = 0.89 Rw = 0,89 TDS = 4,800 ppm If you have any questions please call me at 563-1587. Respectfully submitted by, g~~ Brian Schwanitz Schlumberger Well Services ,~. !"'-~' !~ lumbia Analytical Services Inc. February 10, 1993 Service Request No.: K930542A Jesse Mohrbacher ENSR Consulting and Engineering 4640 Business Park Boulevard, Building D Anchorage, AK 99503 Re: WMRU No. D-1/Project #6397-003-400 Dear Jesse: ~" Enclosed are the results of the rush samples submitted to our laboratory on February 2, 1993. Preliminary results were transmitted via facsimile on February 4, 1993. For your reference, these analyses have been assigned our service request number K930542A. All analyses were performed consistent with our laboratory's quality assurance program. All results are intended to be considered in their entirety, and Columbia Analytical Services, Inc. (CAS) is not responsible for use of less than the complete report. Results apply only to the samples analyzed. Please call if you have any questions. Respectfully submitted, Columbia Analytical Services, Inc. A~eli:f4 Project Chemist AS/akn Page 1 of .-ð ~--. 1317 South 13th Avenue. P. O. ßox 479 . Kelso, Woshington 98626 . Telephone 206/577 - 7 222 . Fox 206/636-1068 COLUMBIA ANALYTICAL SERVICES, INC. ----- Analytical Report Client: Project: Sample Matrix: ENSR Consulting and Engineering WMRU No. D-1/#6397-003-004 Water Date Received: 02/02/93 Date Analyzed: 02/03/93 Work Order No.: K930542A Solids, Total Dissolved (TDS) EPA Method 160.1 mg/L 9ppm) Sample Name Lab Code MRL Result Base K0542-1 5 116 ..r-., No.1 K0542-2 5 6,340 No.2 K0542-3 5 11,800 No.3 K0542-4 5 7,600 No,4 K0542-5 5 6,950 No.5 K0542-6 5 6,110 No.6 K0542- 7 5 7,020 No.7 K0542-8 5 7,300 No, 8 K0542-9 5 7,100 Method Blank K0542-MB 5 ND MRL ND Method Reporting Limit None Detected at or above the method reporting limit -,,^,-. Approved by ú#tp . ~ Date 17/71) nnOO2 .1, \1 J~~' 5f.p1- 51-00 (ensa(' ILO54 z., CHAIN-Of-CUSTODY RECORD /"--'Client/Project Name: Lù tM ~U No. b-l Project Location: Project No. h.397 -t)o 3 - 7'00 field Personnel: V. ný~fl' Field Sample Lab Sample Sample Number Date Time Number Type Analyses Required ß~se- ~ÝZ7 /2.'rD 0 ~ TD~ ¡..6 . I 1z..~l)5 2 ,2..: 05 3 J2-! rb ,>, + /¿ : JD :5 I ¿ =-15 .b 12,'. JS ~ 7 }1,: zl) ~ \¡vi /2- : Zl) " oJ /~" Sampling Rem~rks: ~ ~ ~~ ð ~ s~~ubl UMAIl- . . - ~ fi::;'J- pr (..11 ~ lr'1a ("'1 ( t5 k Iß -to J e.t:6~ m on t'" bl^~ (" @ (q l>1) Z 7 ~ -466~ . ..x: # h ('" -r A -r-/:t> c 11 tp + ~ fY1t:iJ I hard t!opv/ rc'fJ4,f 1(. ~ Il~1 Seal No. -, Relinquis~~q by: / D,te , Time Received by: - L j - . ~t7e Time I7riAil1t;lJAkl1~ 1, ,/tï3 ¡z.,OO ~YV/VV.X¡'h 'Z/ j 13 0'750 Relinquished by: Date Time Received by: Date Time .. Relinquished by: Date Time f!'~ ~ !);'¡"q 3, /' ---'.Name and Address of laboratory: Sample Disposal Method: L- 0 I u J4t /; " ~ A J14iy I; 'c.J S t/~ , Time OqOO EN:R No. 4568 00003 ~. 11.0 FRESHWATER AQUIFER EXEMPTION Stewart Petroleum Company does not intend to submit an application for a freshwater aquifer exemption for the disposal zone (4,289' to 4,351' TVD) in the West McArthur River D-1 well. Formation fluid samples have been recovered from this zone that identify the total dissolved solids (TDS) in the formation fluids to be greater than 10,000 ppm. r--, ,r-~., 11-1 /""'" 12.0 MECHANICAL INTEGRITY The 7" casing identified in the casing program of this application has been pressure tested to 2,500 psi following cementing. The tubing string has also been pressure tested prior to running in the hole. Once injection operations commence, the 7" casing by 2-7/8" tubing annulus will be monitored continuously and pressures reported on the Monthly Injection Report (Form 10-406). ./'""'.., ,./'^'-" 12-1 /"'-. ". " 13.0 WELLS WITHIN AREA There are no existing wells that penetrate the proposed injection zone within one-quarter mile of the West McArthur River No. 0-1 well (see Section 1.0, Property Plat, and Figure 13-1). Two directionally drilled wells are currently located within a one-quarter mile surface radius of the 0-1 well. These are the West McArthur River Unit No.1 well (see Figure 13-2) and Pan American West Foreland Unit No.2 well (see Figure 13-3). The future West McArthur River Unit No.2 well (see Figure 13-4) will be located at the same surface location as the No.1 and 0-1 wells, but will not penetrate the injection zone within a one-quarter mile radius of the 0-1 well. The West McArthur River Unit No.1 well was constructed in accordance with good oilfield practices and all appropriate AOGCC requirements. The West Foreland Unit No.2 well was plugged and abandoned in 1966 after drilling to a depth of 11,948 ft MD. Schematics showing the casing and cementing programs for the above mentioned wells are presented in the following pages. r-. ..r--'o 13-1 ,.r--~ r.. /"-~'. 131' RKB ~ ( 100' BGL ) 1364' RKB ~ ( 1333' BGL ) 4500' RKB ~ ( 4469' BGL ) It£R ENSR CONSULTING & ENGINEERING DRAWING: SCHEIoIDIA DRAWN: Jl/SR C/SC: 1=1 DISK: D/563 DATE: 03/01/93 CHECK: Jt.4 ~ 13 3/8" conductor, drilled and driven ~ 9 5/8" surface, cemented to surface , Tubing: 2 7/8", 6.5#, N-80, 8R, EUE zz TIW Retrievable Packer Set @ 4197' Tubing Tail @ 4203.35 - Perforations 12HPF 4289' - 4351' ~ l' 29# P-110. S-95, N-80. combination string cemented to 1400 ft. FIGURE 13-1 WEST McARTHUR RIVER WELL D-1 SCHEMATIC DIAGRAM STEWART PETROLEUM CO. WEST McARTHUR RIVER UNIT PROJECT 6397-003-400 13-2 ~, 125' RKB/TVD ... 2,201' RKB ... 2,041' TVD ~, 6,211' RKB ... 4,714' TVD 11 ,130' RKB .. 8035' TVD 11,502' RKB ... 8,291' TVD 13,742' RKB 9,851' TVD ,,~, EN:R ENSR CONSULTING & ENGINEERING DRAWING: SCHEMNOI DRAWN: JL/SR C/SC: 1=1 DISK: 0/563 DATE: 03/01/93 CHECK: JM ~ 30" conductor, 310#, X52, Driven ~ 20", 133#, K-55, cemented to surface. ... 13 3/8", 68#, NT80/CYHE, cemented 3,000' above shoe. Top of Liner ~ 9 5/8", 47 and 53.5#, L-80, cemented 3,000' above shoe. Z Z Baker Model D 'SAB-3 Packer set at -13,170' RKB Perforations 12 HPF 13,254' - 13,364' RKB ... 7 5/8", 29.04#, NT-95, cemented 2,000' above shoe. ... FIGURE 13-2 SCHEMATIC OF WEST McARTHUR RIVER UNIT NO.1 WELL STEWART PETROLEUM CO. WEST McARTHUR RIVER UNIT PROJECT 6397-003-400 13-3 .--~'.. ~ 100' RKB/TVD - 646' RKB 646' TVD ~ 2,001' RKB 1,943' TVD .)-" 8,850' RKB 8,202' TVD 9,083' RKB - 8,436' TVD 11,938' RKB 11 ,010' TVD "/"'-"" ~ ENSR CONSULTING & ENGINEERING DRAWING: PANAIIIN02 C/SC: 1 =1 DATE: 03/01/93 DRAWN: Jl/SR DISK: D/563 CHECK: Jill ~ 30" conductor, ~ 100' RKB. assumed ~ 20", 79.6#, cemented to surface w / 1,245sx ~}.:~>,:~~:>~.~'~:;; DC Retainer at 1,910' RKB w/ 50sx cemented above. ... ~ 13 3/8", 54.5#, cemented to surface w/ 1,71 Osx ~.:/f<;.:,~.: '::::< :,::,:::::...:~.<><' "~'~::<:::< ~::~.::: ,".' .: " ,>'.. ,...' Cemented Plug 8,600 - 8,900' RKB Top of Liner ~ 9 5/8", 40 and 43.5#, cemented w / 2,31 Osx = Perforations 4 HPF at 10,600' - 10,670' RKB ~:~ ~\ ~:~;;~;.; Bridge plug at 11,200' RKB with 50sx cemented above. Perforations 4 HPF at - 11,340' - 11,385' RKB ~ ~ 7" LINER, 29# and 32#, cemented W / 700sx FIGURE 13-3 SCHEMATIC OF PAN AMERICAN WEST FORELAND UNIT NO.2 WELL STEWART PETROLEUM CO. WEST McARTHUR RIVER UNIT PROJECT 6397-003-400 13-4 ~. r-" ,/"",-. " 116' RKB/TVD ~ 2,200' RKB 2,048 TVD .- 6,500' RKB 5,118' TVD 11 ,120' RKB 8,471' TVD 11,500' RKB .- 8,685' TVD 13,992' RKB 10,463 TVD ~ ENSR CONSULTING & ENGINEERING DRAWING: SCHEMN02 DRAWN: JL/SR e/sc: 1=1 DISK: 0/563 DATE: 03/01/93 CHECK: JIA ... 30" conductor, Driven ... 20", 133#, K-55, cemented to surface. .- 13 3/8", 72#, N-80 cemented 3,000' above shoe. ... Top of Liner ~ 9 5/8", 47 and 53.5#, N-80, cemented 3,000' above shoe. .- ... 7", 29#, N-80, cemented 2,000' above shoe. FIGURE 13-4 SCHEMATIC OF PROPOSED WEST McARTHUR RIVER UNIT NO.2 WELL STEWART PETROLEUM CO. WEST McARTHUR RIVER UNIT PROJECT 6397-003-400 13-5