The URL can be used to link to this page

Home My WebLink AboutAIO 002 1) 2) 3) 4) 5) 6) 7) 8) 9) 10) 11 ) 12) 13) 14) 15) February 4, 1986 April 22, 1986 May 12,1998 June 4, 1986 October 14, 1986 November 4, 1986 April 19, 1988 May 13, 1988 July 1,1988 December 13, 1988 December 13, 1991 December 17, 1991 January 20, 1994 March 10, 1997 October 6, 2003 ) ) AIO ORDER NO.2 Kuparuk River Unit Pre Application Meeting wi Arco Arco's Application for AIO for Kuparuk Notice of Hearing and Affidavit of Publication Arco's Application Addendum Arco request to amendment application US EP A's termination of EP A Emergency Permits at Kuparuk Arco ltr re: definition of Class II fluids US EP A ltr re: annulus injection and commingling fluids Arco's request to Amend AIO 2 Arco's Kuparuk Administrative Amendment Rule 6 of AIO 2 Arco's recommendations for Inj ection Disposal of Drilling Muds at DS-3R Arco's re: amendment to Rule 2 Arco re: requests modification AIO 2, Rule 6 Arco's recent workovers pm 3F pad E-mail re: Bob Young wllRS AI02 ¡' ì.¡', I" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE REQUEST OF ARCO ALASKA ) Area Injection Order No. 2 ALASKA, INC. for an Area ) Injection Order for the ) Kuparuk River Unit Kuparuk River Unit. ) Kuparuk River Field June 6, 1986 IT APPEARING THAT: 1. ARCO Alaska, Inc. requested the Alaska Oil and Gas Conservation Commission to issue an Area Injection Order permitting the underground injection of fluids within the Kuparuk River Unit for purposes of enhanced hydrocarbon recovery and the disposal of non-hazardous oil field waste fluids. 2. Notice of an opportunity for a public hearing on June 18, 1986 was published in the Anchorage Times on May 12, 1986 . 3. Neither a protest nor a request for a public hearing were timely filed. Accordingly, the Commission will, in its discretion, issue an order without a public hearing. FINDINGS: 1. An order permitting the underground injection of fluids on an area basis, rather than for each injection well individually, provides for efficiencies in the adminis- tration and surveillance of underground fluid injection operations. 20 AAC 25.460 provides the Commission with the authority to issue an order governing underground injection operations on an area basis. 2. The Kuparuk River Unit boundary encompasses a major portion of the Kuparuk River Oil Pool. All existing injection wells and injection well sites planned for this portion of the Kuparuk River Oil Pool enhanced recovery project lie within the Kuparuk River Unit boundary. All existing wells used for the disposal of oil field waste fluids by injection and well sites planned for disposal of oil field waste by injection lie within the Unit boundary. 3. The Kuparuk River Unit boundary encompasses the major portions of accumulations of crude oil within the West Sak Sands and the Ugnu Sands. Injection wells are SÇJ\NNEtl) (J~JN 1 "¡t 20Dll ~ Area Injection Oluer No. 2 Page 2 June 6, 1986 ~ ~: currently operated for an enhanced recovery project for West Sak Sands. Sites for injection wells required for expansion of West Sak enhanced recovery and for the initiation of an Ugnu Sands enhanced recovery project all fall within the Unit boundary. 4. The portion of aquifers described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit are exempted for Class II injection activities by 40 CFR 147.102(b)(3) and 20 AAC 25.440(c). 5. Less stringent requirements for well construction, monitoring and reporting of injection operations may be more appropriate than would be required when injection occurs into, through or above portions of aquifers not exempted. 6. The vertical limits of injection strata and the con- fining formations may be defined in the ARCO West Sak River, State Well No. 1 and the ARCO - BP Ugnu Well No. 1. 7. The strata into which fluids are to be injected will accept fluids at injection pressures which are less than the fracture pressure of the injection strata and their confining formations. 8. Statewide regulations and conservation orders govern field operations except as modified by this order. 9. To ensure that fluids injected are confined to In- jection Strata, the mechanical integrity of an in- jection well should be demonstrated periodically and monitored routinely for disclosure of possible abnor- malities in operating conditions. 10. Injection wells existing on the date of this order were constructed and completed in accordance with regu- lations which conform to the requirement of 20 AAC 25.412. 11. The Kuparuk River Unit constitutes a project area operated by a single operator. NOW, THEREFORE, IT IS ORDERED THAT the rules hereinafter set forth govern Class II underground injection operations in the following described area referred to in this order as the affect- ed area: SC/%~~~\!ED \J!UN 1 t';( 2004 / f Area Injection \ No. 2 Oraer Page 3 June 6 , 1986 UMIAT MERIDIAN T13N R8E Section 1 , 2, 3, 10, 11, 12, 13, 14, 15, 23, 24, 25, 26, 27, 33, 34, 35, 36. T13N R9E Section 1 , 2 , 3, 4 , 5, 6, 7 , 8, 9, 10, 11, 12, 15, 16, 17, 18, 19, 20, 21, 22, 25, 26, 27, 28, 29, 30, 31, 32, 33, 34, 35, 36. T12N R8E Entire Township. T12N R9E Entire Township. T12N RI0E Section 1, 2, 3, 4, 5, 6, 7 , 8, 9, 10, 11, 12, 14, 15, 16, 17, 18, 19, 20, 21, 22, 23, , 25, 26, 27, 28, 29, 30, 31, 32, 33, 34, 35, 36. T12N RIlE Section 5, 6, 7 , 8, 31. TIIN R7E Section 24, 25, 26, 34, 35, 36. TIIN R8E Entire Township. TIIN R9E Entire Township. TIIN RI0E Entire Township. TIIN RIlE Section 5, 6, 7 , 8, 16, 17, 18, 19, 20, 21, 22, 27, 28, 29, 30, 31, 32, 33. TI0N R7E Section 1, 2, 3, 4, 9, 10, 11, 12, 13, 14, 15, 16, 21, 22, 23, 24, 25, 26, 27, 28, 33, 34, 35, 36. TI0N R8E Entire Township. TI0N R9E Entire Township. TI0N RI0E Entire Township. TI0N RIlE Section 5, 6, 7 , 8, 17, 18, 19, 20, 29, 30, 31, 32. T9N R9E Section 3, 4, 5, 6, 7 , 8, 9, 10, 13, 14, 15, 16, 17, 18, 19, 20, 21, 22, 23, 24. T9N RI0E Section 1 , 2, 3, 4, 9, 10, 11, 12, 13, 14, 15, 16, 21, 22, 23, 24, 27, 28, 33, 34. 8CAh!NED "JUN 1 !? 2004. t \ Area Injection Orûer No. 2 Page 4 June 6, 1986 ~, T9N RIlE Section 5, 6, 7, 8, 17, 18, 19, 20. Rule 1 Authorized Injection Strata for Enhanced Recovery Within the affected area, non-hazardous fluids may be injected for purposes of pressure maintenance and enhanced oil recovery into strata defined as those strata which correlate with the strata found in ARCO's West Sak River State Well No.1 between the measured depths of 3145 fèet and 3640 feet; 3744 feet and 4040 feet; 6474 feet and 6880 feet. Rule 2 Authorized Injection Strata for Disposal Within the affected area, non-hazardous oil field fluids may be injected for the purpose of fluid disposal into strata defined as those strata which correlate with the strata found in ARCO's West Sak River State Well No. 1 between the measured depths of 3390 feet and 3640 feet, and with the strata found in ARCO - BP Ugnu Well No. 1 between the measured depths of 8370 feet and 8800 feet. Rule 3 Fluid Injection Wells. Fluids may not be injected underground except through a new well that has been permitted for drilling as a service well for injection in conformance with 20 AAC 25.005, through an existing well that has been approved for conversion to a service well for injection in conformance with 20 AAC 25.280, or existed as a service well for injection purposes on the date of this order. Rule 4 Monitoring The Tubing/Casing Annulus Pressures. The tubing/casing annulus pressure of each injection well must be checked weekly, as a routine duty, to ensure there is no leakage and that it does not exceed a pressure that will subject the casing to a hoop stress greater than 70% of the casing's minimum yield strength. Rule 5 Reporting of Tubing/Casing Annulus Pressure Variations. Tubing/casing annulus pressure variations between consecutive observations need not be reported to the Commission. Rule 6 Demonstration of Tubing/Casing Annulus Mechanical Integ- rity. A schedule must be developed and coordinated with the Commission which ensures that the tubing/casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, must be held for 30 minutes SCANNED JUN 1 7 2004 ~ Area Injection Oruer No. 2 Page 5 June 6, 1986 \~ with no more than a 10 percent decline. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Rule 7 Well Integrity Failure. Whenever operating pressure observances or pressure tests indi- cate pressure communication or leakage of any casing, tubing or packer, the operator must immediately cease injection, notify the Commission, and obtain approval for corrective action. Rule 8 Plugging and Abandonment of Fluid Injection Wells. An injection well located within the affected area must not be plugged or abandoned unless approved by the Commission in accor- dance with 20 AAC 25.105. Rule 9 Administrative Relief. Upon request, the Commission may administratively amend any rule stated above as long as the operator demonstrates to the Com- mission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. DONE at Anchorage, Alaska and dated June 6, 1986. ¡, 69i~ Ollo ~ ~~~ ", ~ ~~¿oiØ Çji({f4n Alaska Oil and Gas Conservation Commission -/, (2 L~mit", ommissioner Alaska Oil and Gas Conservation Commission .-' .'..~ q;:"". , SCANNED JUN 1 7 2004 n 7) lll��i 11f WALT ER J. NICKEL, GOVERNOR ALASKA OIL AND GAS 3001 PORCUPINE DRIVE CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 27, 1994 ADMINISTRATIVE APPROVAL AIO NO.2.6 Re: Amend Rule 6 to allow additional means for demonstrating mechanical integrity of injection wells Paul S. White, Senior Engineer Kuparuk Petroleum Engineering ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK. 99510-0360 Dear Mr. White: ARCO Alaska, Inc. (ARCO), as operator of the Kuparuk River Unit, by letter dated January 20, 1994 requested the Commission modify Rule 6 of Area Injection Order No. 2. The modification would allow use of a variety of logging devices to demonstrate mechanical integrity of injection wells. The commission has determined that alternative means for demonstrating mechanical integrity of injection'wells is appropriate. This approval supersedes Area Injection Order No. 2 Rule 6, and Administrative Approval A.10 No. 2.4. Therefore Rule 6 of Area Injection Order No. 2 is amended to read: Rule 6 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission which ensures that the tubing/casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi, or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater; but not to exceed a hoop stress greater than 70% of the casing's minimum yield strength. The test pressure must be held on the tubing/casing for 30 minutes with no more than a 10% decline. Alternative EPA approved methods may also be used with Commission approval, including but not limited to timed -run radioactive tracer surveys, oxygen activation logs, temperature logs and noise logs. Wells with tubing -to -casing communication must be Mr. P. s. White Page 2 November 27, 1994 ) ) surveyed or logged every other year and wells which demonstrate mechanical integrity every fourth year. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests or the application of alternative methods. BY ORDER OF THE COMMISSION ~ L~ c:J, L1->T_-cye~ Russell A. Douglass, CommiS§1oner Alaska Oil and Gas Conservation Commission 1vj~ 0~ Tlc~erman Babcock, Commissioner Alaska Oil and Gas Conservation Commission 117 0 A3 N ALT �I W ER J. H/CKEL, GOVERNOR ALASHLA OIL AND GAS 3001 PORCUPINE DRIVE CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 December 27, 1991 TELECOPY: (907) 276-7542 ADMINISTRATIVE APPROVAL AIO NO. 2.5 Re: Amendment to Rule 2 of Area Injection Order (AIO) No. 2 A. Wayne McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Dear Mr. McBride: Pursuant to your written request dated December 17, 1991, for amendment to Rule 2 of AIO No. 2 to allow disposal into the Upper Ugnu sands in an area of the field where these sands are not oil bearing, Rule 2 is amended to read as follows: Rule 2 Authorized Injection Strata for Disposal Within the affected area, non -hazardous oil field fluids may be injected for the purpose of fluid disposal into strata defined as those strata which correlate with the strata found in ARCO's West Sak River State Well No. 1 between the measured depths of 3390 feet and 3640 feet; and with the strata found in ARCO/BP Ugnu Well No. 1 between the measured depths of 8370 feet and 8800 feet; [and] within tract ADL 25648 (Sections 3, 4, 9, and 10, T11N, R10E, UM) into the zone which correlates with the strata found in ARCO's West Sak River State Well No. 1 between the measured depths of 3145 feet and 3390 feet[.]; and within portions of tracts ADL 355023, ADL 355024 and ADL 373301 (Sections 3, 4, 5, 8, 9 and 10, T13N, R9E) into the non -hydrocarbon bearing portions of the zone which correlates with the strata found in ARCO's Oliktok Point Well No. 2 between the measured depths of 2937 feet and 3544 feet. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION SCANNED J C:y�, printed on recycled paoer h Telecopy No. (907) 276-7542 December 20, 1988 f. D M J. ~N..I S T ~ A,T JM,V,E ~.p,~..l\ 9 V ,A.. ,L, A..!w"O NQ,.~,.4 Re: Amendment to Rule 6 of Area. Injection Order (AIO) No.2 to allow Radioactive Tracer Surveys (RTS) as an alternate method of demonstrating mechanical integrity. M L Hagood, Manager Kuparuk Operations Eng ARCOAlaska., Inc POBox 100360 Anchorage, AK 99510-0360 Dear Mr Hagood: ARCa Alaska, ItlC (ARGO), as operator of the Kuparuk River Field (KRF), by letter dated December 13, 1988, requested that the Commission amend Rule 6 of Area Injection Order No. 2 to allow the radioactive tracer survey (timed-run log) as an alternate method of demonstrating tubing/casing annulus mechanical integrity in Kuparuk River wells. The Commission has determined that timed-run radioactive tracer surveys (RTS) offer appropriate means for demonstrating mechanical integrity of an underground injection well. Therefore, as provided by "Rule 9 Administrative Relief", Rule 6 is amended to read: .. . .... --,.. ~U~~"1;"'7 2001 F<~(' .'\~"~Ali¡"',: i ~ j1\1 , :i, ;.,' '0V.r'\~~5~~~ ~ J~ 2... .\ Administrative Approval AlO No. 2.4 December 20, 1988 Page 2 ~u~e 6 Demonstration of Tubing/Gasit!g Annul,us Mechani.cal. Inte~:r,i~y A schedule must be developed and coordinated with the Commission which ensures that the tubi:ng/casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, but not to exceed a hoop stress greater than 70% of the ca.sing's minimum yield strength, must be held for 30 minutes with no more than a 10% decline. As an alt~rn~tive, with Cc>,lnmisst9n~ppr<?val ~ in.iection ~el1~inay-be, s,uryeyed US~l1g a timed-run radioactive,.trace.17, s-q,rvey ~RTS) every othe}; ye~r,.,~or wel~s ~ith. tl.!bing-,to,-casing communicati<?n"and. every fourth year for ~ells which demonstrate mechanical integrity_ Thè' Commission must be 'rlotif'iêd at least 24 hours in advance toen.(:lble a. represen.tative to witness pressure tests or the, runn~ng,of RTS·~. Sincerely, l?~ì' ........ORD.. .i:.··.·· ~.~....._...)T. H./.)E....... COlvfM. . TSSION C· "~!fÄj; /. I I. . . ....._.... .,i' .. ... ,1.1/ ~~.... ..,/. . . ,. __--....... / .. Ý· {)r .~. .... J /,. ~-~.~- /.1 '. ")1 ;¡¡;~, . 'I . /, /j vr/'{I· >1../'2';" r j ....,.r' ,,-- ( r v V Chat"terton· . ;(ha . fma.n ((...... /---') /' ~ [/ \/".' "' ..... . , ( -r/ ii' '\(YV'~ . ~/¿ Lonnie C Smith Commissioner jo/3.AA AlO 2 st;¡:\\Nð~E[' JUN 1. ? 200£1 Telecopy No. (907) 276-7542 July 7, 1988 A D H ~_."~..,,I_ ~ ,...T_. R,A T I V E A}? g .1.1 q, y ~ L A. ..! q"þl 0." 2 ..~ Re: Amendment to Rule 2 of Area, Injection Ordør (AlO) No. 2 C D Davidso11 Kuparuk Operations Manager ARCO Alaska. Inc POBox 100360 Anchorage, AK 99510-0360 Dear Hr Davidson: Pursuant to your written request da.ted July 1, 1988, for amendment to Rule 2 of AlO No. 2 to allow disposal into the Upper Ugnu sands in an area of the field where these sa.n.cis are tlOt oil bearing, Rule 2 is amended to read as follows: ;ßu 1 e 2, "A2:1 th()1~,i z~dI nj ec t io:t~ S t:t".~ t:.§. .. f.<?:r" P.i,~ P,c>.s éE',~, Within the affected area, non-hazardous oil field fluids may be injected for the purpose of fluid disposal into strata defined as those strata which correlate with the strata found in ARCO's West Sak River Sta.te Well No. 1 between, the measured depths of 3390 feet and 36/..0 feet; and with the strata found in ARGO/BP Ugnu Well No. 1 between the measured depths of 8370 feet and 8800 feet; and within tract ADL 25648 (Sections 3, 4, 9, and 10, TI1N, RIOE, UM) into the zone which correlates with the strata found in ARCOvs West Salt River State Well No.1 between the measured depths of 3145 feet and 3390 feet. Sincerely, ,,' /y":1 'I..·., .,' ...-...... '\., ," ... ,. J'_"".{ Lonnie C Smith Commissioner jo/3.AA AID 2 (;:.: ¡j'.' /\ 'i\\ i"li ~::::- .. 01 ¡j\. J '1 ;''';'? 0 n:' ",) V ¡f""\'.!J Jj,H..... ,.--. Ji) ~ ~~ _tj ,,-. :..J't Telecopy No. (907) 276-7542 October 27, 1986 ADM I N I S T RAT I V E A P PRO V A L N o. 2.2 ..~ - Re: Amend Rule 7 of Area Injection Order (AIO) No. 2 Mr. T. !'vI. Drumm Operations Coordinator ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Hr. Drumm: The Commission has determined that Rule 7 of AIO No. 2 as set forth is unclear as to the Commission's intent. Therefore, Rule 7 is amended to read: Rule 7 W~ll Integrity Fail~re Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must [IMMEDIATELY CEASE INJECTION,] notify the Commission on the first working day following the observation, [AND] obtain Commission approval [FOR CORRECTIVE ACTION] of a plan for corrective action, and when a.n USDW is not endangered, obtain Commission approval to continuè ·iniection. (J. i. )er~1Y ,/...-....,/-'. J . 1/ ""7/('/ It .¿¿,.,<- .'1 f) ., . . '1'7 . . i . \.~J%'l¿;t- C. V. Chatterton Chairman jo/3.AA AID 2.2 ~Ç^,NNEr.\ JUN 1 7 200,1 'Ii:, Telecopy No. . (907) 276-7542 October 27, 1986 ADM I N 1ST RAT I V E A P PRO V A L . N O. 2.1 Re: Amendment to Rule 3 of Area Injection Order (AlO) No.2 Mr. R. A. Ruedrich Drilling Manager ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Ruedrich: Pursuant to your written request dated October 14, 1986, the Cotmnission has determined that Rule 3 of Area Injection Order No.2 is incomplete and unclear as to the Commission's intent. Therefore, Rule 3 is amended to read: Rule.3 flu~d _Ini~.ction "'~~lls The underground injection of fluids must be: 1) through a new well that has been permitted for drilling as a service well for injection in conformance with 20 MC 25.005; 2) through an existing well that has been approved for conversion to a service well for injection in conformance with 20 MC 25.280; or 3) through a well that existed as a service well for i.njection purposes on the date of this order. Pumping of excess non-hazardous fluids that are developed solely from well operations, or necessary to control the fluid level of reserve pits, into surface/production casing annuli is exempted from the above requirements. jo/3.AA AlO 2.1 -'"((or> I' & I' II C-" ~\1 ;N i; 10-"1 20n f1 ~v/¡·-·~~r,.lt\\:;IL-:i:.., <:}U~' 1 {: ;... v'} #15 Phone Message 10/6 10:30a Subject: Phone Message 10/6 10:30a Date: Mon, 06 Oct 2003 11 :00:44 -0800 From: Linda Berg <1inda_berg@admin.state.ak.us> Organization: AOGCC To: Jody Colombie <jody_colombie@admin.state.ak.us> Bob Young Engineer with IRS Oklahoma cell 405-590-4081 wrk 405-297-4890 but never there Needs copies of AIO 2, 2.1, 2.2, 2.3, 2.4, 2.5 & 2.6 ) Please call him -- if we are charging him for copies he will need to know approx how much so he can get authorization. Linda VI '7 r\O \ì '1 0 u \ 0 8Ct~Nh~EC JlJN 'Î [") 200" .... _c.- .. ~. J. i: _ ,,!.J. 1 of 1 ¡:; /Ó Ã., 10/6/2003 11 :06 AM #14 SENT BY: ARCO ALASKA ; 3-10-97 17:32 KPS/WELLS/CNST/PROJ~ 907 276 7542:# 11 1 ~ , , ') ARca AlaSka, Inc. Kuparuk Operations Post Office Box 196105 Anchorage. Alaska 99519-6105 } ~;~ ~~ Eric L. Zuspan Wells Engi.neering Tech Kuparuk Wells Group NSK-69 PhOr'1e: 659-7285 ~ax: 659·7314 March 10j 1997 Mr. Blair WondzelJ Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Blair, Listed below is the information you requested on the recants Workovers on 3F pad that had MIT's performed this week. I included information for 3F-07 that was tested on 1/25/97. WeJls 3F-03, 04, 07, & 08 were worked over for the following: Replaced tbg (BTC.. non gas tight connections) for MI service / Profile Modifications. TtI Costs 3F-03: $1,536,591,00 3F-04: $1,027,329.00 3F-07: $340,124.00 3F-08: $465,865.00 If you have any questions, please calli . Sincerely, &.-/þ- Eric L. Zuspan r''\ ·,C:. \..,,;1[::, ~ \1 E:: (,) .'\ \,1 ' . . - G - í'il L\ i~ ¡ , (9:.J r ·~t(]:;~·~~5 .'~ (:~a::: {~;i:;~}.:;. ~·~~;rnH~~S~~~(:(: ~\ 7~ ·.~hci' :~~~~.; .~: i\RCO Alaska. Inc. 19 a Sui1~idÌ<1ry of AII9ntIC RfCl'lrEJld Company #13 ARca Alaska, Inc. ) Post Office Box.;1 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ,I) .,";OM~~ cð.~' :COllli~ I~l~ ~SR ENG 1:1 SR--ENG I ENG ASST I i ENG ASSmi, SR GEOL #cL.· GEOL As§Í"i ~ ' ~~OL As~iiíb\ 1\ STAT TECH I ¡I ¡ STAT TECH , FU.,¡E" , } ~"..-"-:':... '.- January 20, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: ARCO Alaska, Inc., Operator of the Kuparuk River Unit, requests that the Commission modify Area Injection Order 2, Rule 6. Applicant requests that Rule 6 of Area Injection Order 2 be modified to allow use of a variety of logging devices for alternative Mechanical Integrity Tests (MIT's). This Rule was previously amended to include the use of radioactive tracer surveys on December 20, 1988 in Administrative Approval No. 2.4. Use of radioactive tracer surveys has become increasingly difficult due to regulatory and environmental constraints. Technology advancements in well logging have produced other methods of demonstrating mechanical integrity including: oxygen activation logs, temperature logs, and noise logs. These logging techniques have been approved by the Commission for use in the Milne Point Unit, and in the interest of operational efficiency should also be approved for Kuparuk. Use of these other methods will in no way reduce the quality of Kuparuk's MIT program. Please contact me at 263-4241 if you have any questions. Si nce rely f>tJ P. S. White Senior Engineer Kuparuk Petroleum Engineering RECE\\JED J t>J\ "\ 9 '994 comm\ss\Of\ .,' ~ f' lú\ &. Gas Cons. :' k ,,\,a I\ncnoragf) Mnn-!)OO:1!!:~ '1" I' r¡;'~(¡\~:I:;:'···' b "\.;; ~\ UiJ ß ~ II:. ~...J "1 ~)' 20 flJ. ~~ ~i ' ~ ~~J , ?·1??(i03 #12 \ ARCa Alaska, Inc. ) Post Office.. . 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ') ~~ !..c~~~r:~'.._"-' ... I GO~M ~' 'COMM .. 'RE_~__§NG ~ SR .§_~~ tB I SR ENG )It( ¡ ENG A~§.U_..¡ ; ENG ASS~T : SR GEO .·'../"r ' \ GE~.~~~~lJ-··~ GEOL ASS~ Ii STÄTTÊ'(jH I 1 , ST ATTËÓH I FILËAA -!f,oZ'.( December 17;1991 Mr. David W. Johnston, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Kuparuk River Unit Area Injection Order No. 2 Dear Mr. Johnston: ARCO requests an amendment to Rule 2 of Area Injection Order NO.2 to allow injection disposal within the Kuparuk River Unit 3R pad area into non- hydrocarbon bearing zones of the Ugnu C which occurs between 2634' and 3005' subsea (2937' and 3544' MD) in Oliktok Point Well NO.2. The 3R pad area covers Sections 3, 4, 5, 8, 9, and 10, T13N, R9E. These sections are located in portions of ADL 355023, ADL 355024, and ADL 373301. ARCO is planning to drill a disposal well on 3R to inject drilling muds and cuttings and other non-hazardous fluids developed from drilling and production operations on the 3R pad. The current plan is to utilize the existing approved injection zone for disposal. The disposal well's planned bottom hole location is to be approximately 500 feet away from any other planned well bore path on 3R to avoid problems with communication during times of injection. The bottom hole location is also planned in an area where the approved injection zone is expected to be below the oil-water contact with the best chance of finding a suitably non-hydrocarbon bearing zone for injection. If hydrocarbons are encountered, however, and the well could not be used for injection, it would be possible to drill on to a Kuparuk target, though this location is not ideally suited for that purpose. Also, in the event a Kuparuk target were drilled, a location for another disposal well would still need to be found. RECEIVED 'JI,.,bcr'-, J'JN ""II ~( 70 f"r¡ SCJ\N~~I!.-:t...> ,. ~ ).~ J. [ ,.) I,)"J D ~'C 1 ß 1991 ARCO AI<lsl<i1, Inc, is i1 Subsidiary 01 AtlanticRichfieldCompany Alaska UII (~ ll;7i:~ Cuns. LJuu1mission AlL:¡: (ì11iJ:·: c: Anchorage \ ) I· ) Mr. David W. Johnston, Commissioner December 17, 1991 Page 2 The disposal well will be the first well drilled on 3R and is expected to spud in mid to late January. An internal ARCO memo is attached which explains the geology at 3R and correlates the approved injection zone in the West Sak River State Well No.1 to the Oliktok Point Well No.2. The memo identifies the Ugnu C in the Oliktok Point Well NO.2 as the requested alternative injection zone. The Ugnu C was approved for injection in July 1988, by Administrative Approval AIO No. 2.3 at 1 B pad (ADL 25648). We are requesting approval to use the Ugnu C also at 3R, only if the currently approved injection zone for 3R is completely hydrocarbon bearing and cannot be used for injection. Our geologists would be happy to meet with you at your earliest convenience to discuss this request and answer any questions. If you would like to set up a meeting or need additional information, please contact Ellen Fitzpatrick at 263- 4638. Sincerely yours, t/~~~ Area Drilling Engineer R EQEIV ED DEC 1 B 1991 Alaska Oil & Gas Cons. L.\..;,;¡1\\SSlon Anchorage Ii Ii B f,l 'r¡ ú}1 20 O'~ C'· I.}, ·,1 .:.. (!. "rr r ~ ,~~ ~~ ~ f==\ C~.¿ i"'..') ~:::J t:::) ~.;;;:, » i5J U) ~ ¡:u Q C) ~ Pì >ø 0 :::I PJ g.(/) -' Q b' cn PJ ::::: c.a eÍJ ~~ (,D· (.~ Co (..0 o _,..I> :3 8. ü) (f) Q' ;;c m ~ rn - < rï1 ÇJ > ~ ~ = t') =- a tÞ = .... ..... T-3 SAND BASE PERMAFROST K-15 MARKER UGNU C UGNU B UGNU A K-13 INTERVAL WEST SAK SANDS WEST SAK UPPER MEMBER WEST SAK D WEST SAK C WEST SAK B WEST SAK LOWER MEMBER WEST SAK A4 WEST SAK A3 WEST SAK A2 WEST SAK A1 WEST SAK BASE LOGGERS TOTAL DEPTH DRILLERS TOTAL DEPTH 1705.00 1755.00 2075.00 2937.00 --:3544.00 3725.00 4160.00 4335.00 4335.00 4335.00 4387.00 4459.00 4498.00 4498.00 4585.00 4660.00 4765.65 4885.00 8243.00 8280.00 2075 1755 2937 3544 3725 4160 4335 4885 4498 4387 4459 4498 4885 4585 4660 4765 4885 4885 8243 8280 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 65 00 00 00 00 1651 1699 2001 2686 3058 3151 3369 3475 3475 3475 3509 3558 3586 3586 3649 3702 3778 3862 6879 6916 26 39 86 63 34 64 61 14 14 14 37 99 75 75 26 93 00 76 36 06 "- -1598.28 -1646.39 -1948.86 -2633.83 -3005.34 -3098.64 -3316.81 -3422.14 -3422.14 -3422.14 -3456.37 -3505.99 -3533.75 -3533.75 -3596.28 -3649.93 -3725.00 -3809.76 -6826.36 -6863.06 350.58 0.00 684.97 37 1 . 50 93.31 218.17 105.33 387.61 111.61 34.22 49.63 27.76 276.00 62.53 53.65 75.07 84.76 0.00 0.00 0.00 QES QES QES QES QES QES QES TQES BQES BQES BQES BQES 0.00 520499 0.00 520504 0.00 520536 0.00 520694 0,00 520899 0.00 520975 0.00 521187 0.00 521270 0.00 521270 0.00 521270 0.00 521293 0.00 521323 0.00 521339 0.00 521339 0.00 521375 0.00 521405 0.00 521449 0.00 521498 0.00 521709 0.00 521709 . 16 6028541.82 .45 6028554.37 .65 6028652.70 .58 6029139.49 .56 6029571.80 .37 6029707.06 .80 6030017.24 .13 6030130.06 .13 6030130.06 .13 6030130.06 .15 6030161.72 .75 6030203.95 .81 6030226.15 .81 6030226.15 .27 6030275.16 .96 6030317.64 .32 6030378.03 .37 6030446.25 .38 6031700.67 .35 6031705.31 RAD 321 334 438 949 1424 1577 1945 2081 2081 2081 2119 2170 2197 2197 2257 2308 2381 2464 3702 3706 .2 .7 .0 .6 .6 .8 .0 .5 .5 .5 .8 .9 .8 .8 .2 .7 .9 .7 .2 .5 ~, FORMATION/MARKER/ZONE NAME ------- MEASURED DEPTH --- ---- TOP BASE TRUE VERTICAL TOP SUBSEA TOP QUALIFIERS -x- DELTA - ------ -- STATE SOPACH T1 T2 B B2 THROW PLANE -Y- STATE PLANE US WELL STATUS - WELL DESCRIPTION API # 50-029-21103-00 WELL NAME OLIKTOK PT 2 OPERATOR ARCO ALASKA INC LAT/LONG 70.48829 N / 149.83311 W Y/X COORD 6028231.14 / 520417.69 SURFACE LOC T13N R9E S9 UMIAT SECTION FT 149.00 S 2094.00 W DATUM 53.00 KB / 12.00 GL SPUD/COMP 08APR84 / 05MAY84 PLUGGED & ABANDONED TIE-INS: CONTRACTOR JOB # METHOD START DEPTH STOP DEPTH DIRECTIONAL ARCO ALASKA, INC. SHALLOW SANDS DATABASE REPORT CONTRACTOR JOB # METHOD DATE START DEPTH STOP DEPTH SURVEY DESCRIPTIONS: SURVEY ID "0" EASTMAN WHIPSTOCK- A0484Z0259 GYROSCOPIC 25APR84 0.0 8280.0 SURVEY(S) RUN SURVEY TELECO 0 370-AK SINGLE SHOT 09APR84 0.0 7836.0 - LOADED ON D "1" LFIELD SERV DATABASE SURVEY D 2 "' '~-~ #11 ARca Alaaka, Inc. ) Int.rnal Corr.ap ')nce Date: December 13 1991 ~-... ~". Recommendations for Injection Disposal of Drilling Muds at DS-3R Subject: From/Location: G. Wilson T. Eggert ANO 914 X4748 AN0950 XI663 To/Location: E. Fitzpatrick ATO 1450 X4638 Introdnction This memo outlines recommendations from Kuparuk -Geoscience for an injection disposal well at DS-3R, which is planned if annular pumping is not used for drilling mud and cuttings disposal. The AOOCC-approved injection disposal interval (defmed for the West Sak River St. No. 1 well in Area Injection Order No.2, Kuparuk River Unit, Kuparuk River Field, June 6, 1986, Page 4, Rule 2) was previously identified in well Oliktok Point 2 (May, 1991 memo: T. Eggert to R.M. Brush). The purpose of this memo is to address the concern that the approved interval, as correlated to Oliktok Point 2 and projected to the 3R Pad injection well location, may not entirely satisfy the criterion that an injection disposal interval be completed and peñorated in a non-hydrocarbon- bearing sand (application for Permit to Drill, injection disposal welllR-19). Steps to avoid drilling a hydrocarbon-bearing injection disposal interval are outlined below. In addition, a contingency plan for an alternate injection disposal interval (in need of AOOCC approval) is recommended in the case that the approved interval is hydrocarbon-bearing. ~baUow Sands Geoloric Summary. DS-3R Interpretation of Well Oliktok Point 2: ¿-Shallow sands formation and marker picks are summarized in Attachment 1. The approved injection disposal interval within the U gnu Band A sands (as correlated from the W. Sak No.1 well) occurs in Oliktok Point 2 between 3005' and 3317' subsea (3544' and 4160' Measured Depth) (Attachments 2, 3 and 4). Sands in the upper 52' of the interval are oil-bearing. An oil-water contact is interpreted at 3057' subsea (3643' MD). Sands within the injection interval below this oil-water contact appear wet, with the exception of 12' of sand at the base of the interval. The wet sands within the interval may have residual oil based on relatively low resistivity log responses. Alternative wet sand injection zones (not approved by the AOGCC) occur below permafrost but above the Ugnu B (3005' subsea, 3544' MD) in Oliktok Point 2 (Attachment 4). These same sands are expected to be encountered in a well drilled from the pad at DS- 3R. Local U gnu B Structure: A structure map prepared from well data for the top of the U gnu B (top of the injection disposal interval) indicates that the interval is deeper to the northeast (Attachment 5). Faults are not included on this map. Note that although regional trends are smooth and consistent, local deviations in the top structure trends become apparent around well control data points at each pad. Similar small-scale irregularities are expected at 3R as more data becomes available. A brief examination of five northeast-southwest trending 2-D seismic lines revealed a down-to- the-northeast "structure" along the coastline at DS-3R. This structure is not interpreted as a fault, but rather is interpreted as a statics problem with the seismic data caused by the on- shore/offshore transition. Because of this static problem, fault interpretations along the coast at DS-3R are regarded as tenuous. ARCO Alaska, Inc. is a Subsidiary of AdanlicRlchfieldCompany AR3B-6001-B ~Ç¡\N~\!E[J~JUN 1 ~J 2004 '.ge 2 '~ ) ) ,,, ~J Recommenda tion~ Target the Approved Injection Disposal Interval Below the OWC: Based upon the top Ugnu B structure map (Attachment 5), the only way to reach sands of the injection disposal interval completely below the oil-water contact is to drill northeast (down structural dip) of the conductor . location (ASP Coordinates: X=520671.67, Y=6031S99.81). This assumes that the well plan configurations beneath/northeast of the 3R Pad will pennit injection into the shallow sands without affecting (by overpressuring) the drilling of subsequent 3R development wells. The local dip on the top of the interval, as projected northeast from where it is encountered in Oliktok Point 2, requires that the target location for the injection well should be a minimum of 700 feet (preferably more) northeast of its conductor location in order to anticipate wet sand. At this location the top of the Ungu B is expected at about 3075' subsea. IT the disposal well is drilled to a target closer to the pad, the sands of the upper Ungu B can reasonably be expected to be hydrocarbon-bearing. These considerations are all based on the assumption that significant faulting does not offset the U gnu northeast of the last control point - Oliktok: Point 2. Contingency Plan - Obtain Approval/or an Alternate Injection Disposal Interval: A contingency plan for injection disposal is advisable in the event that the Ungu B sands are not encountered below the oil-water contact or are otherwise unsuited for injection disposal at DS-3R. Contingency approval should be sought for injection disposal (local to 3R Pad) into wet sands of the Ungu C, which occurs between 2634' and 3005' subsea (2937' and 3544' MD) in Oliktok Point 2 (Attachments 1 and 4). Sands in this interval in Oliktok Point 2, identified by inspection of the gamma ray, deep resistivity, and density logs, commonly are 20 feet or more in thickness. Deep resistivity values in these sands typically range from 2.5 -5 ohm-meters, which contrasts with 20 - 30 ohm-meters for sands of both the upper 53' of the Ungu B and those sands above the Ugnu C but below the base of permafrost. Ugnu C sands from 2735' to 2795' subsea (3088' to 3184' MD) and from 2875' to 2945' subsea (3315' to 3435' MD) appear to be particularly good peñoratioo zones for injection disposal of drilling fluids. In order to minimize the risks and uncertainties associated with drilling an injection disposal well at DS- 3R, an approved contingency plan should be in place prior to drilling the disposal well. If further evaluation by geoscience is necessary, please contact Kuparuk Geoscience through D.S. Hastings. ~ C!. W~ ~son Geologist Kuparok Development and West Extension Geoscience · JL-- 4~ J.T. Eggert Geologist Kuparok Development and West Extension Geoscience Attachments cc: J. Golden D.S. Hastings T.L. Hudson G. Phillips W. T. Thomason ATO-II46 AN0-920 ANO 946 ATO-1170 AN0-908 ARCO Alaska. Inc. Is a Subsidiary of AtlanlicRichfieIdCompany AR3B-6001-B ~ [¡ 1;\1 of, ~"? 2 n fI ,II SCf\tl~~ NEI) j d ~;\ J if .- u.fr T-3 SAND BASE PERMAFROST K-15 MARKER UGNU C UGNU B UGNU A K-13 INTERVAL WEST SAK SANDS WEST SAK UPPER MEMBER WEST SAK D WEST SAK C WEST SAK 8 _~EST SAK LOWER MEMBER ('\olE 5 T SAK A4 ::)/EST SAK A3 :)~EST SAK A2 ~EST SAK A 1 ~EST SAK BASE ~bOGGERS TOTAL DEPTH ~DRILLERS TOTAL DEPTH ;:~ þ ~ pj'- ~ U> ^' I--~-'" ç.J r'-l ~ ~ f2.J c=J ,... G> <":'':' g PJ :'J"' if¡ (") C~ rJ ~: '-~ -J i/~ (.) . r-.· c:' :~ :"3 (1' A;4 C) r-Tt In r") C') -~ rr-ì C.-,1 ----.......- -' c.;;,:~~....... c:.D fT'! (0 _..i r:.') > pot. S- f') =- a tþ = pot. ..... 1705 1755 2075 2937 --'3544 3725 4160 4335 4335 4335 4387 4459 4498 4498 4585 4660 4765 4885 8243 8280 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 65 00 00 00 2075 1755 2937 3544 3725 4160 4335 4885 4498 4367 4459 4498 4885 4585 4660 4765 4885 4885 6243 8280 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 65 00 00 00 00 1651 1699 2001 2686 3058 3151 3369 3475 3475 3475 3509 3558 3586 3586 3649 3702 3778 3862 6879 6916 .28 .39 .86 .83 .34 .64 .81 . 14 .14 . 14 .37 .99 .75 .75 .28 .93 .00 .76 .36 .06 -1598 -1646 -1948 -2633 -3005 -3098 -3316 -3422 -3422 -3422 -3456 -3505 -3533 -3533 -3596 -3649 -3725 -3809 -6826 -6863 .28 .39 .86 .83 .34 .64 .81 .14 .14 .14 .37 .99 .75 .75 .28 .93 .00 .76 .36 .06 350.58 0.00 684.97 371 .50 93.31 218.17 105.33 387.61 111.61 34.22 49.63 27.76 276.00 62.53 53.65 75.01 84.76 0.00 0.00 0.00 QES QES QES QES QES QES QES TQES BQES BQES BQES 8QES 0.00 520499.16 6028541 0.00 520504.45 6028554 0.00 520536.65 6028652 0.00 520694.58 6029139 0,00 520899.56 6029571 0.00 520975.37 6029707 0.00 521187.80 6030017 0.00 521270.13 6030130 0.00 521210.13 6030130 0.00 521270.13 6030130 0.00 521293.15 6030161 0.00 521323.75 6030203 0.00 521339.81 6030226 0.00 521339.81 6030226 0.00 521375.27 6030275 0.00 521405.96 6030317 0.00 521449.32 6030378 0.00 521498.37 6030446 0.00 521709.38 6031700 0.00 521709.35 6031705 .82 .37 .10 .49 .80 .06 .24 .06 .06 .06 .72 .95 .15 .15 .16 .64 .03 .25 .61 .3 1 321 334 438 949 1424 1577 1945 2081 2081 2081 2119 2170 2197 2197 2251 2308 2381 2464 3702 3706 .2 .7 .0 .6 .6 .8 .0 .5 .5 .5 .8 .9 .8 . f .é.~ .7 .9 .7 .2 .5 WELL DESCRIPTION API H 50-029-21103-00 WELL NAME OLIKTOK PT 2 OPERATOR ARCO ALASKA INC LAT/LONG 70.48829 N / 149.83311 W Y/X COORD 6028231. 14 / 520417.69 SURfACE LOC T13N R9E S9 UMIAT SECTION FT 149.00 S 2094.00 W DATUM 53.00 KB / 12.00 GL SPUD/COMP 08APR84 / 05MAY84 ----------------------------------------- WELL STATUS: PLUGGED & ABANDONED ---------------------- -------------- MEASURED DEPTH FORMATION/MARKER/ZONE --- ---- NAME ------- TOP BASE TRUE VERTI CAL TOP SUBSEA TOP ._----,..~ QUALIFIERS -x- DELTA - ------ -- STATE SOPACH T1 T2 B B2 THROW PLANE -Y- STATE PLANE RADIUS I I I I I I J I I I I I I I I TIE-INS: CONTRACTOR JOB II METHOD START DEPTH STOP DEPTH CONTRACTOR JOB H METHOD DATE START DEPTH STOP DEPTH SURVEY DESCRIPTIONS: SURVEY 10 "0" EASTMAN WHIPSTOCK- A0484Z0259 GYROSCOPIC 25APR84 0.0 8280.0 SURVEY(S) RUN SURVEY TELECO 0 310-AK SINGLE SHOT 09APR84 0.0 7836.0 - LOADED ON D "," LFIELD SERV 1'-' I I I I I I I J I I I I t DIRECTIONAL ARCO ALASKA. INC. SHALLOW SANDS DATABASE REPORT DATABASE SURVEY o 2 .... Ii KUPARUK RIVER UNIT BOUNDARY OJ!: 3-R~ I .f.?tJ OUKTOKPT..' 3-Q 3-0 L 30.08 r 3-M 3-N·· ~ 3-T r -{ 3-1 ~3-H Ba_ 3-A ) ~ ) Attachment 2 - 3-J 3-8 3-G 3-F 2-W -- 2-U KUPARUK - 2-T 2-X PARllaPA llNG ' Þ:, 2-V AREA 2-A ..,- 2-C 2-8 [ 2-M 2-H ,2-F / 2-G ~ 2-L 2-K I , ?-p I I I U I 3-C I .... UGNU swpr f - ... 1-R ':L fR-D7 1-K 1-A 1-8 1-C 2-Z 1-F 1-E 1-D 2-D I "J 1-L ' I I 2-E I I I I CROSS SECTION LOCATION MAP (See Attachments 3 and 4) RECEIVED D1:"G '1 c\ '¡(''¡91 ~ '~' \~1", ¡ ,l\laska Oil & Ga~) '..,·(:;1S. cornmisS\OJ1 Anchorage (c:r{-Þ\MIW,¡:":i) ~1! ~r.-JJI.1 1 ? 7r.lO/~ V~.r-"""~:J \;\,\,1 ';~~"I(''''''' 10.1..1' ~~~ ~'ci .._~. " - ~ JUN 1. ~I 20021. ·""";¡:'·W:"·l . "~~I . ~ . ; .~~ ,. ': I~ , ~.. : ~;:~ ~. : ',~\ "'"\._'" I' ,.~~ , 1 ~, :. ,. ~~~::: :~~.=. ~ ---- &... . . II I' 1"«· ¡.' "~: ~ ~- ,'\ '-:::, ., ......... . -;., ....:' I ~ .;t..: :::; " , , ~ :.;,:;:: I ".~ ~ ~- ~I ~::G, . ::.:¡ ;to . , ~"..,~~..,'" ~ r ' . I .;or,:~", ~ ~:'': ( , , ;~ ~ r-7~,,,,). .., 'f' (... J=:.: :~:~ " ,~~ ''''1-:;,: ; ,~:; ,....:).0#-- ~' )r - I 5.". ":'" ~,' '. \ , ':;,'. ; :;'1 ..,.... I~ , ~; ~ · . '.7' ,,'!:.... I ,. ~' ¡:o ~:;" "" ~ ...., _,.' , ~, ',1 ~ t I)~ ~. ~ ~~~ ~ ~ ~ ' . ,; ; '~ ~u.·< 4 ~ '" ~. . ~,I,..:.I '9" ····~:~'~I ¡¡¡r!~!iil 'i!~I~lli!tl'¡i~' ,. , ... VjL "--.: ~ ) .t. ~ ; ,-i ' . ..~ ., .. ,. ,.. ,.. . .. -: ,. ,'\, :;·~¡ï " 7- ~ i ~ .~.- " .... ~ . ~ ,,_ wi ~' ~ -¡'~- " ""'"" . , ...¡ .. ... - -, ..,.. ..,. ARCO OLIKTOK POINT 2 API 500292110300 Attachment 3, DEC 1 8 1991 Alaska Oil Ô Gas Cons. comnÙSS\on Anchorage RECE\VED TOp WEST SAl( SilSE INJECTION ZONE -3057 owe TOP INJECTION ZONE I 111-" : ~i¡~~ ~.~~ '. : E:: , [W:~~·}., u~:: I !!iJ I ! !,..-!t hi J :1" "I :1"":"-' ÞO' . "'''.~.'.'''''''.¡''.''I.' ~ :-i11rE . _ J'rJ. ,':!'''~ I. _ ~ ," jiiF,~¡i~ :~,:>.. .:~~:'~!!~~!;¡.;:;:¡: i "''1... ,; ¡¡.,t J,. '.. ; : ~ :::n : : ¡.::~ '" I !iH'~i !iiY~, , " ,,,tI "'(" ""!~ÜIL:·1r,aiÆ..:·: .,'~' :"1 .!! . ; n::tr: !f1~r ~ ~,.',I; ~ ~I"¡' -. . ¡ ~; :::j. .: f~r\'~ IÞIi-lIn; _(, I L ..' ~::~,. .:':: rri. ~ '~ :..~~~ .~~ ¡ ¡ijl:~r ' .:" , ""¡'fi I .1"';'" ! :¡!Ir~ '. 11111.. ~.,;~"'i ..~J'1:k.;!' :~ ',"- ~.~ !::~;;~ . : ~~::;:,.-l . f :if¡:r~;~~,:l J F n:;¡.-' ~ , r ~ ., \ ; m:~( . .'~ ,~~::: : ;~::;r~ ...;" I~IIII;' ''\:.' ":' ~ ':'111'£11" ,.... 'µ¡:,~ . ~ ..\~\~\It!" ~, ,~.....;' I :I'II~ \. .. " : !r~:;L) , CI::~'J ,~ ., -, ., .,. :! 1~ ~~~~ ~;~i~i :~ ~ ~ J " ';" ~' I ~A~' " , \~~ , · -> ,I'~ , ' ., (, ~, ~ -~ ..... -- .,~ J .- ".", " , ~ ,~- I '. .'.~ ~,,' . q' -' . '):':'" "':.~ ',~ t: , .~. "1 ~:-~ ~ .~,Q ,'... ,~ ", 111.-- ,_'" '. I , .~:.~ ,·~r~ '~ ,. ,. -, ,. I" ARCO NEST SAK RIVER ST. API 500292009000 APRIL 24. I ~9' --------------------------------------~----- J. T. EGGERT OLIKTOK PT 2 3542 "D. 3004 SUBSEA 4161 nD. 3318 SUBSEA NEST SAK 1 TOP 3390 no, 3304 SUBSEA BASE 3640 no. 3554 SUBSEA AUTHORIZED KRU DISPOSAL INJECTION ZONE WITHIN THE UGNU SANDS INTERVAL VERTICAL SCALE: 1 IN. = 80 fT. (SUBSEA CURVES) NOT TO TRUE HORIZONTAL SCALE "\'/ SOUTH-TO-NORTH ) } SECTION CORRELATION CR \ " \ 10 -2-t49 + .......... \ SH)OOO I ...~. ~" ~ s S ii Attachment 5 Top Ugnu 8 Structure Map Scale: I" = 4000' c. I. = SO' -:~~ I.' . ~ :~ . ~'..:'.."~~ - , . ." ..... . -... - f\' . '. .";':,"' ... r·- . . , , 1:l- ft:¿' -Cf} ~{)of~ - ~ s'!'~ 11~s /~~C- '0YOCJI:Jut-ov- ~ ~~/ C4~!vd/ ~:.r . J / .~ /" ~c.--l ceCx$~ -Æ'L- #cd . ) #10 ARca Alaska, InL ) Post omce 8m( 100360 Al!'1Ichorage, A~aski31 99510-0360 Telephone 901 276 1215 ') Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 n~~ 2~""'Z:\ .~ I'I);\~T-T ! ~.º.l ¡~:rr~;~;[JlI I ¡ I'lf¡~~~~ :::::;:;;~:~'::;;¡';I!"-¡ ....... ? rÞ- ",J/:;: (.,~/, ~. 'Jrl),À ~Lo.--,& '7 J ' December 13, 1988 Dear Mr. Chatterton: Subject: Kuparuk River Field Administrative Amendment - Rule 6 of Area Injection Order No.2 In accordance with Rule 9 of Area Injection Order No.2, ARCO Alaska Inc. as Operator of the Kuparuk River Field requests that the Commission administratively amend Rule 6 to allow the radioactive tracer survey (timed-run log) as an alternate method of demonstrating tubing/casing annulus mechanical integrity in Kuparuk River wells. This type of survey, as outlined in the Federal Register on December 10, 1987, has been approved for this purpose by the EPA. Also with reference to Rule 9, there would not be any increased risk of fluid movement to an underground source of drinking water from this amendment, since there is no such source within the Kuparuk River Field. If additional information is required, please advise. Sincerely, l1/~'Ge~4~1 j. *~~p M.L.Hagood (I Manager, Kuparuk Operations Engineering MLH/HGUbak D f'" r r" ~ , I !r" ....." .. I!o-' ~ F ~ ~" \" ~ .: ~I '~ L. ~, L ~ ~r L. t.,)' In., r.... 1',\ 1 ' , 1 !:- \' i" I 0 8 .~"). .,-- L..·· . 1 ,) 0 Alas;œ. G;¡ & (;3:) CCil2. CClJ1rnissfoE Anchorage l\RCO ,~Iaska, Inc. is a Subsidiary 01 A!lan!id~ichficldCo"'IJ;:m\' ,,-,.( . \II\j Ï\I:C:'" ¡ 1J \\,1 J "'1 200 ~ .."'~ '...".;-, LJ Ij L L..J ~..!\ j ~ ,;. j I . u~~ #9 \'t'4 ARca Alaska, Inc. J! Post Office Box '100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 J u 1 y 1, 1988 ~~ ~~~."..i COMM ~~.L' COMM ~ RES ENG "-D SR ENG Q3. ~R ENG lit ,ENG '1 SR GEOL I SR GEÖl I .. ,ENG ASsr JJr' -ËNG ASST J_ sfÃt-fËCH\ 'STATTECHI 'FiLe: .,f' Mr. Chat Chatterton, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Kuparuk River Unit Request for Amendment to Area Injection Order No.2 Dear Mr. Chatterton ARCO Alaska, Inc., as operator of the Kuparuk River Unit (KRU), requests the Alaska Oil and Gas Conservation Commission (AOGCC) amend Area Injection Order No.2 to include the following: \ ·*.f ~ø ,0 .!!.> Modify Rule 2 injection strata depths to include the zone which ''t'l(~'~ .Jð'lf' c carrel a tes to the strata found i n ARÇO'sW~.~.t?ª~Riy~!.:._?_!.?_!~_~e~,~_~o. \I'.$~? t føß<ð 1 between the measured depths of 3145 feet and 3390 feet (In addltlon,!,' ~ to the a 1 ready permi tted depths) .-..-....''"'....''''.......''..... . ~\Åt;. ., Injection into the above mentioned strata meets the following two requirements for issuance of variances under the Commission I s dis- cretion: 1) injection is not into, through, or above a freshwater aquifer, and 2) injection does not result in an increased risk of movement of fluids into a freshwater aquifer. The aquifers underlying and extending one quarter mile beyond the KRU boundary are exempt from the definition of freshwater. Injection within the boundary of the KRU is not into, through or above freshwater, nor does it involve risk of movement of fluids into a freshwater aquifer. The zone currently permitted for injection is the Lower Ugnu, which corresponds to 3390 feet to 3640 feet measured depth. The zone requested for inclusion in the Area Injection Order No.2 is the Upper Ugnu. The Upper Ugnu is included in Rule 1, which allows for in- jection into this strata for enchanced oil recovery purposes. The intent is to use the Upper Ugnu to dispose of non-hazardous, Class II reserve pit water (Attached is a letter from the EPA verifying the designation of this water as Class II water). This disposal of reserve pit water is required to come into compliance with EPA regu- lations for discharges. The upper Ugnu has been used for source water production for Increment I Waterfl ood. The zone wi 11 be i nj ected i nto through~,. e~.i11..t,i.f\~ W1èl ~ . l,.)\".¡ ~·,.¡~UI,' p" L. \,.. L Ü >¡r IL.. . SCA~~NED JUN 1 ? 20D:} ,Jut --(; 1~~!:JB ARGO Alaska, Inc. is a Subsidiary of AtlanlicRichlieldCompany Alaska Q'¡I & Gas Cons. Commission Anc:1QiJçe -, )1 Your favorable and timely consideration of this request is appreci- ated. si/~fcer~.y ~OUít, {]&Ja~ c. D. Davidson Kuparuk Operations Manager 11;'~. 1f··..···t.\h~t~lrc:f.· .11¡1¡NV 1. ~; ?oqll V'bJ.?"I"~~·~~ ö¡¡..,..l, <.Hh· .J!. £ L.' L , 3200 '- Figure G-la ') ARCO WEST SAK RIVER STATE 1 SEC. 2, T.11N., R.10E., UM OR LL8 SO 100 1 10 100 ~ .~ ~ - ~ '> J t ? ,:;= 3400/-~ -- ~ r ~ ~, ;5 I 3600 '- L-- l I I I I I I 3800 '- 4000 '- ~ ,.." ~ t t > ? ( I UPPER UGNU' SANDS t '"- I I i "'). LOWER UGNU SANDS ) + ;?Gl.f.O 37t-f-tf t / J ,$' I 4,5"' I ./ )~ i( ;. I/, \ . \ i j) WEST SAK SANDS /) J + .... ..' K,.·1.2" i'- ~ ~ ~ .. :) l :;.:.!.....,.. ¡~> :.' ( ~'" ß. ~ :1,1,. h·"_~ Lr ol(\) 14a .¡ ( ;! ..... (', Alasl<a GlI K Ga.s Gens. C:)!1'¡¡TJ,(ss:on ¡ 1 11\1' ~ ? 2nl'lc'1. fJ \)Ú ~ _,~_ ~ "..J ~.,,; .) ·..,.,......~ ,.~\....,. i!t~ (.j)~:~;~:; !ri~~ BASI ~::~:~ PERMAFROST: Interbedded gravels, sands and shales. 'IIMII" . .:'~".. ~.. 'ROST :.: ';::. ..:: . °t' .., . ..' T'~ ~ji~JIll¡ T-3: ~:~~e~a~~;~e~~~ ~:~~~a~~da~~a~~~~rlain with inter- :2¡~~~ - . First coal marker underlain with sands, silts and K-15 :-:-;:-:~: K 15. sha1es. Localized coals occur within this interval. tÜ~:1¿i'~ i-~;~ i~~~~;~;~ UP'II XT.T.~:~~7;~ UPPER UGNU: Interbedded coarse to fine sands and sha1es. UGNU ::;~.~~~~: LO¥tI.~~~~~iÞ LOWER UGNU: Interbedded coarse to fine sands and shales. - - - - - - - UGNU :7~-¿7:"::: tn WEST ().~,~~·:.0·:~ WEST SAK SANDS: Interbedded fine sandstones, siltstones, ::;:) ~ SAK ~~:~~~~~- and c 1 ays . o ~ SANDS @~~~;fl~ W" :':;:'.\:;::::::'; o W ::{·r..::-:.:I"·: c( ~ I- ~ W 0 a: 0 o 'IIIOD > a: <C - I- a: W ... I I I I I I Figure G-l GENERALIZED STRATIGRAPHIC SECTION LITH- MAI.'I 0\00'( DISCII'TtON z o - ~ :& a: o u. ~ o ... ~ a: ~ > tc( CJ tc( U) K-12: Inter1aminated si1ty mudstones and sha1es with minor si1ty sandstones. Based on data from: 'ARCa West Sak River State #1 14 j 11\\1 .~ \';1? n p}, ~:) \.} ~ ~ ...~, {¡~.. ~J ...j J JUL-01-'88 09:35 ID: J L-t.- I 1_'" r · L ì: ') KIC LAB \ Kuparuk Industrial Center )~ Operated by Piquniq Management Corporatton Li -.., I·..· .. . - f?ouoh 340065 * Prudhoe Bay, AK 99734-0065 Tel (907) 659-6'30 * Telefax 659·6188 June 28. 1988 Report 10. 06880.5 lIe LAB RIPORT or a.1LYSIS 'ROO 1LAS11 IIC. ",1RVI: OIL L,'8 1TT.: 808 "TRICI 'S'-72tt 'MALYSIS or , WiSTI SiM'LI ......a......................**..*a..............~.......................~. S1",!.B 'OXIT 110 LAB SAKPLI . DATI/TIMB SàHPLID luparuk Dru. Pit later 88060110 06/25/.8 '.30 IR ...............~......................a~.*........=.....~.~................ I Speoific Gravity Liquid Oont.nt . Solidi CODtent I t.oo )g'.51 <0.51 I' TOIIOITY 0."aOTI"18'·108: "'11M'" 'LLOI'8LI LIMITS ¡OIlIT'.I..ITY.. ('ll'h Poi at, r) CORROSI'ITY. (pi) RI'CTJ'11Y .I..TIR RB&OT¡.¡ty I'IVDROO&RBOIS )1tO 1. t "0 DO >i.O >2 - <12.5 no DO --~-~--~~~--~~~~--------~----~--~~~~~~~~.~-------~--------~...._----...--~- I' TOXICITY HIT'LI p.~ 81-8&6 11\81110 .V/L "RI8" -ilL CiÞMIU" a,/L OIROMIUM .,/L LI'D .,/1. MIRC1UtY -IlL 8BLIJlIUM MOIL SIL'IR .g/L RCRA I&Z1RDOUS "jSTS: 10 CO""IIIT I: < O. 01 0.1 <0.01 <0.5 <to 0 < O. 001 (0. 01 <0.5 5.0 '00. 1.0 5.0 5.0 0.2 1.0 5.0 RECEIVED ! I f'- - 1 1988 Alaska Oil & Gas Cons. Commission Anchorage . __J!tij.£~~---------------_.~~~~- ..ALYST' ã;~---~-- LtboratorJ Maaa,.r pag. t of 1 ,~·;(;/~\lf\jNE!:" ~1¡ UIIq "íl 'ì' 2nrV1 ......- J" '- \ L...rj ~._¡, t,J f \~ J" ~I ..,.,' ~I ....~" '¡, ') ,\, ') CHE¿\fICAL & GEOLOGICAL LABORA TORIES OF ALASKA, INC. P.o. BOX 4-1276 Anchor~ge, Alaska 99509 Telephone: (907) 562-2343 WATER ANALYSIS REPORT OPERATO. ARCO Alaska, Inc. WELL NO FIELD Kuparuk COUNTY STATa Alaska DAT~ July 8, LOCATION FORKATION IKTBRV AT. 8AlIPLE FROV.. ANCHORAGE INDUSTRIAL CENTER 5633 B Street 1983 LAB NO. 2837-2 y;'SW- 3 !tEUJ\.RXB Ii CONCLUSIo~a' Barlurn (Ba), lTg/I ----------1.4 StDontiurn (Sr), rnq/l----------0.86 Iron (Fe) l rnq/I ------------0.28 Oil & Grease, Irq/I -----------1.7 Turbidity, ntu ----------0.84 Suspended Solids, mer/I ---------7.0 Dissolved Iron, m:r/I --------<0.10 CI:tfcu ~.....~ F:~~ O\~ - . v.~ '.~ In. '. - - - .s.!! 1015 5.~ 4.8 _ _.. 7.8 A.rJona Sulfa te ~ ..- Carbocate :s Ic&rbonate H,.drox1de .æ5!! 44.1 6 0.13 ?40 0.64 - - - - . . . . . - Total Ca~ 47.33 _ . . . . - - -------. ... - Total ~ ~ rq!1 NeCI eqafn1tat, mall . - - . - Ot.u...6d pH .. - . . 2718 2632 7.8 8~ ~ @ ~·F.: O~ - - - - CI\\c-nLo,ud .... okm-mcQn oCm-lIICtÐra Na :' Ca ,. HI F. ", :1 " I --:- J WATER ANALYSIS PATTERN ScaJe HEQ per Unit S.a.mple above de-:.m1>ed f It! \ 1 ''':': ~ ~ ! " r~;\'¡ i ", I' \1 ~ï ¡ i L} I J 11'1'1 I,! ' 1, ¡ .,.1'1' T r".ld!. tJ Ai, t." ¡, r " I I Cl 10 N. . 11 ¡ HCOa Ca ' I· 1 ¡ I SO~ Mg I"] 1 . Ii , t I co. Fe ~··1 I. 1 ~¡ ----"-i , . I : ~ 1 L. I. I. I 311 <1.0 _ 1_440 410 .!!5l! o 40 _ fi1 o 6.7? TouJ Anloca 47_i~ . . . . /..5 /..6 RECEIVED· .HJL -11988 Alaska .oil & Gas Cons. Commission , AnchQ("r ~ I .!1 ;.1 't . I ' . ,. ~~ ¡; ¡ ; I !1; ¡ ; 1 fl¡¡;' " ' I ì 1 I , I!d 1;:1 'IiI: . ¡;; ; ¡:I ,! I' I ~ I II' ì ~ I !H· I !,II . . ¡' , 1 'H.t¡ . ~ :. !:I I ¡I i ¡ ; ¡ , j.. ' d. ¡!~dl' , Cl HCO. so. co. (Xl..... ill ~ v..- ~ "" I. ... U) If on: 1£ 1/1:: Jit1tlu-=- p.- h:r ....n:: ua%:;tna ~ pc ~ s.Gaa ~ ~:~~ ~ . H~ ~'-~-'_.. &aa ;.- $'- ~.~ct\N~"E[J <c~UN 1 f?:. 2D Dl) "'lli ') \ ') CHEt.fICAL & GEOLOGICAL LARORA TORIES OF ALASKA, INC. P.o. BOX 4·1276 Anchor~ge, Alaska 99509 Telephone: (907) 562-2343 ANCHORAGE INDUSTRIAL CENTER 5633 B Street WATER ANALYSIS REPORT OPK2.ATO. ARCO Alaska, Inc. DAT~ July 8, 1983 LAB MO- 2837-3 WZLL JII 0- LOCATION FBLD Kuparuk FORHATION COIDt~ INTERVAl. STAT· Alaska SAMPLE PROK.. WSW 4 REKA.JtXS .t CONCLUSIONS! Barium (Sa), mq/l -------------1.5 Strontium (Sr), mq/l ----------0.81 Iron (Fe)! mq/l --------------<0.10 Oil & Grease, mq/1 --------------0.75 Turbidity, ntu ------------------1.2 Suspended Solids, mq/l ----------3.0 Dissolved Iron, mq/l -----------<0.10 ~ .s!! ~ A.rJona .!!!!! l!5!! ~.t . .. . - 1 nq4 47.61 Sulfa te <1,0 0 ~~ . . .. . . 4.~ O. 1? C1ùocide . .. 1580 44.þ6 ("kf- . ~4 ?nq Cuboaate 0.. V-r w{IQA 7.f> O.n? Bkubonate 395 6.4e _ Iraa . .. Hydroxide Total Ca&aa 51.04 Tota) ÅIÜoDI . . . . 51.04 - - ---.... ... -- T021 ~"nd ~ rq/l ?q35 specific ~ @ ~·P.: HaCt ~ rrcll .. . .. . .. . . ?~5? Oll! .,Ie . .. .. .. ?S obm-rDIItuI ObrAl..d pH - - . . .. .. . . .. .. 7.8 ('II ,,"t..~. IS . .. . .. ?4 cJ:m..~ WATER ANALYSIS PATTERN Sc&Ie Sampl, abov, descnòect !IRQ per Unit . HJ f ; I ; ; !! I N. 'L,¡: ¡ 'I í- I : I j , I t I..~ ¡i j I LI .. W Ca . 1;1¡ i ~;J¡¡ I' HI .:: r ' ::_, f ' If "11 I, .,11 W !! 1 F.:¡I,q¡.'·..~¡tJr 11.;1I!.. I' , d I ¡I, I t ~ t t " ' ''1:;, . .1 II' .¡fjl, I, ' " ~ ;L" ~ t t, I : . i "1 t I It ¡ j j: HCO~ 1 c. '11 ' , ' ¡ I :~~-L!~. , '....-...- ,. :l L :-: '::~;1 i. : i 1; . "¡' , , I' , Cl ClIO Na HCO~ so. 1 AIr 804 CO~ 1 Fe I " I I·: co. ,I. iL r, I..· n.!' r (.. .u.. ill ~ ~ ~ XL ~ ... LI) .on: .ú1=)(~ ~ Ih:i% XWi\f1= KD:Ic'r- ..~ta pc It_ ~ --- ~==.., ~. H~ _."..,'~ &.... -.-' I" ~C"'ANNCTI"\ R¡JN J '~I ?O[í;'1 '~.;]J ~,I \ ... L.. t'....I c;¡J ~ _." li t::..., .,'; l' \ ) c~ ) CHEftlICAL & GEOLOGICAL LABORA TORIES OF ALASKA, INC. P.O. BOX 4·1276 Anchor~ge, Alaska 99509 Telephone: (907) 562-2343 ANCHORAGE INDUSTRIAL CENTER 5633 B Street OPE]lATOR WZLL RO. PIELD COUNTY STAT&. WATER ANALYSIS REPORT ARCO Alaska, Inc. DAT~ July 8, 1983 LOCATION Kupa ruk P'ORJiATION INTERVAT. Alaska 8AKPLB FROV., HSW 5 LAB HO- 2837-4 U1U.EX8 .t CONCLUSIONS: . Barium (Sa), mg/l -------------1.6 Strontium (Sr), mg/l ----------0.82 Iron (Fe), mq/l --------------(0.10 Oil & Grease, mg/l -------------0.70 Turbidity, ntu -----------------1.1 . Suspended Solids, mg/l ---------7.0 Dissolvpd Iron~ mq/l ----------<0.10 Cztioca .s!!. ~ ArJona .sa .!!!9l.! ßo..Hr- - - - - - 980 42.65 Sulfa te - <1.0 0 ~-~- 4.8 0.12 Ch10ride - .. - _ 1400 39.48 ('-tø:Jn- . . . - . . 51 2.54 CubaGate . 0 "'·w\..."iL'" - - - - . 7.9 0.65 Bicarbonate . - - . - 395 6.48 Iroa - . . . - . - H,.dro:dde 0 To31 Catloca . . - . 45.96 ToÞJ A.n1oaa 45.96 - - ...--...- To:! ~ ~ rq/l 2638 8~ ~ @ ~·P.: HaCI eq~ 1'l2II1 . - - . - 2556 O~ - - - - 2.4 œm.mtas'I O~pH_ . . . . - 7.8 C"k'n'-tl<! . . . . 2.6 obm-met13rI WATER ANALYSIS PATTERN Sca1e &mpl. abov, dnaibecl MEQ per liGit ï! II I I I I ¡ . . ! I I 'J 1 10 Na ¡." I ' j,' . 1 Cl Na Ct - ~ . I 11'1. . I 1.1 ,I ' I · · i'. ; I .. : i j. 11 t , Ca Iii I \., Ilï I~ HCO~ 1 c. ' HCO~ ¡ 1 I I I" I I : ! 1 ¡ II IIII ¡ J(1: "'ir1 I ¡ d' J¡" I He 'I ! 1. : ¡ .1, ¡., I! ~ _ ¡ ,J ¡ I S04 1 Yg 804 ¡ i J fL· ¡ t ,~ ; I , I ' t I I" ¡ . .' t .. ¡ ~ I t¡L!J" ' . ~ q', ~ F. _!l¡p! ,!,.~¡jl" ;.¡¡f1l!¡' " CO~ 1 Fe CO. I¡!!:d )' ;11'11 !!I illiJ~H, :\: :f'HI.hLLIIII.' l' 1 I t ()fa.... .. ~ ~ ~ )f.. K. .. U) won It¡/) )( JI( i'" ')001 : = ~ ¡;c ~ ~= K:srcr- ~u ~~/\.ij \M~~çr n IN :1. :í L ! ¡lie a.e:ma ~ ~~W D--. . H~ .0 _.~ &i*"IÇ' ~".!lc... i "..... -' \ ) CIIE~fICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. Telephone: (907Y 562-2343 ANCHORAGE INDUSTRIAL CENTER 5633 B Street P.O. BOX 4· 1276 Anchor~ge, Alaska 99509 OPERATO. WELL ICO- PBLD COUNTY STAT. Kuparuk WATER ANALYSIS REPORT ARGO Alaska, Inc. DAT"R July 8, 1983 LOCA TION FORKATION IKTERV AT. SAMPLE FROV.. LAB HO. 2837-5 Alaska WSW 6 UKA.RXS .t CONCLUSIONS: Barium (Ba)~ mg!l -----------------1.5 Strontium (Sr)~ mq/l --------------0.90 Iron (Fe), mg/l -------------------0.41 Oil & Grease, mg/l -~------------0.63 iJrbi di ty, ntu ---------- ------ --2.2 - Suspended Solids, mg/l ----------5.0 Dissolved Iron, mg/l =----------<0.10 Orti::ca .!!&l! !!!i!! ArJon. .!!!I!! .!!5L! ~!'t'ftIt - . . . . 1004 43.67 Sa.1f.a te <1.0 0 ~ 5.1 0.13 CbJoride . . 1400 39.48 c.tM- - · · · . . 48 2.40 Carbœate 0 IC·I,....·J~ · · · . . 8.0 0.66 Bka.rbornta . . . . . 450 7.38 In. · · · - - H)"dro:dde Total Ca~ . · · . 46.86 Tot&) AnJoaa 46.86 -------..- TOÞJ ~ ooZ1da, ~1 . . · · . 2687 8peciftc ~ @ ~·P.: HaC1 eqc!n.1=t, m¡l1 . - · · - 2592 O~ . - . . 2.40 okm-~ Ob4wlC..-;I pH . - - . . 7.8 ~\(-n'",~,i . . . 2.6 a&m-m&Un ,I ., WATER ANALYSIS PATTERN SaJe llEQ per Unit i~1 . ¡ I -+-i:.¡: --"-+., -,.-< . , Na ::::t:'-',-,,;: ~.-r,-~. o·t ..;.--+-r-¡ -~ - i '"I ' Ca I I ,.- . SampJe abov. detcnDed J ! I, . I t, ¡ . I ' Na , Ij, , , I; , :: ! Ca' n: 11 , :1 He, ¡ : I' i' : I· . I '" F. j ! ¡ j; I . Jil'11 ., ~ll * , ·i~))" ~I : ,;.~ I , ¡ . I. . "'. t. I ',I , f ( . Li' Cl 10 . I Cl . HCO. 1 , HC03 I ' ..: 'so. 1 Mg, , so. 'C03 1 Fe co. " , (M. .... ill ~ u...- ........ Jfa. K.. ~ U) Sf" t\ ~~. W Erl ~ UN 1 '7 2 0 O'~· .on: 1f&f1=1f9.çlol pw )b;r &hq/1= Ktmcr- ~u pet J1tif"-.>,:r~ß'IJ -" ,. t .- Io6aa dIJori6e ~=.., 0--' . H~ ~, . -L. &..: '1- .. #8 10 U.E )IRONMENTAL PROTECTION A "'~)y REGION 10 1200 SIXTH AVENUE SEATTLE, WASHINGTON 98101 ,~E.O sr../: v~ ~\SI :' ^ ~ "'= - % -~I.IJ ]; " <¡ ~ ~ r! 1-, ,,~ -4( PRO"\~v r.IAY 1 3 1988 REPLY TO ATTN OF: WD-1 32 William T. Christian ARCO Al~ska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Dear Mr. Christian: Thank you for your letter of April 19, 1988, regarding annulus injection and commingling of fluids. Subsequent to our meeting of March 30, 1988, we met with the Alaska Oil and Gas Conservaticn Commission (AOGCC) to perform a mid-year progress review on the implementation of the Underground Injection Control (UIC) Program for Class II wells in Alaska. As follow-up to this meeting, the Environmental Protection Agency (EPA) and AOGCC are revising the Memorandum of Agreement (MOA) for the UIC Program to address the annulus injection issue. As we discussed in our March 30 meeting, reserve pit fluids and precipitation can be injected into an annulus as long as the fluids are not hazardous waste or surface runoff. The MOA will incorporate Paul Ba1tay's November 24, 1987, guidance memorandum to clearly state that such annulus injection is not covered under the UIC Program unless the practice is abused to circumvent the intent of the UIC Program. In conjunction with AOGCC, we consider abuse to occur when the annulus of one well is used excessively as outlined in Robert Burd's May 6,1987, letter. AOGCC will decide on a case-by-case basis whether a well is excessively using annulus injection. Your April 19 letter accurately documents our March 30 discussion of your questions related to the commingling of fluids injected into Class II wells. We would consider drilling fluids, mixed with snowmelt that collects in the reserve pits, to fit within the types of fluids defined in Mr. Cook's July 31 , 1987, memorandum to the Drinking Water Branch Chiefs. After our discussions with AOGCC, the Commissioners concurred with this view. Under the terms of the guidance memorandum, future "calls" on whether a particular fluid fits into one of the "classes" defined in the memorandum are the responsibility of the program director. Thus, any questions which ARCO has in the future concerning the commingling of fluids in Class II wells should be referred to AOGCC. t;~ ~: ¡}"\.. ít~ cr; r ~' ~ u r- -.", ) : i i I -. Ai2ska CU ß{ Gas Cens. r'~'11~: ' Är,.-.h,..."" v.JJI'/¡\dSSiOì: , ,¡ ".I U) (¡lie ~"';C,I\ ~\! N Er n ~ f\¡ 1 'ì ''"¡ íí 1"1,< -,.. ) ) - 2 - It is EPA's understanding that AOGCC's Area Injection Orders and Disposal Injection Orders authorize fluids to be commingled in Class II wells for a specific operator and field as long as the fluids are not hazardous and are related to oil and gas production. Also, as we understand the intent of these permits, they do not authorize injection of fluids such as domestic waste and wastes from third parties (eg. service companies). These AOGCC "policies" are, in our view, consistent with the guidance issued in Mr. Cook's July 31 memorandum. I hope this information is helpful. Sinc~e~ùS<.. / \ <"'i, " I 1\..). V Dick Thiel, Chief Drinking Water Programs Branch cc: C. V. Chatterton, Chairman, AOGCC Dennis Kelso, ADEC, Juneau Larry Dietrich, ADEC, Juneau Pete McGee, ADEC, Fairbanks Mike Hotchkin, Assistant Attorney General, Alaska Y") t:.: 1..~~· ¡. ~. ;.',:,_", t ~-':'''' too: 'It t~ ~.~ !. \ ¡ ~ (j A:'.........·\rr.¡ C;¡l & (:::S (~C;n3. S2,fTl8fsslon )ç.:J "\c~ ~ . .I~~~i C ~~ 'J rZlse S/" [\~, ~ ï:ç:r i\¡ fi1i\'1 -í' [;, 2[ \".., t.~'!ì· b .'1~\!I..'at'.' ,J .,.J)¡\ J.. ! __ JUL-01-'88 09:35 ID: TEL NO: tf033 P02 L, KIC LAB ) Kuparuk Industrial Center Operated by Piquniq Management Corporation -~, I'., .... ..-- eouch 340065 * Prudhoe Bay, AK 99134-0065 Tel (907) 659-6130 * Telefax 659·6188 June 28. 1988 Report 10. 06880.5 110 LAB RIPORT or AMaLYSIS AROO aLASIA J MC. II,iRUK OJ I, L,A8 &TTI: B08 ,aTRICI 65'-721. \\es¿,~\J~ P~t liLo '"ALYSIS or 1 WiSTI S,"'LI .....M............................&........a.....~~......................B. S&"'I.I 'OJ 1fT 110 LA' S'"'LI . 0ITI/TI"1 S'H'LID luparuk Dru. Pit Water 88060170 06/25/" '.30 IR .....~................................a..*........:....~.........*........s . Speoific Gravity Liquid Content I SolidI Cont.nt I 1. 00 >SÞ!Þ.51 <0,51 I' 10lIOITY O"RACTlaIST·IOS: NAIIN'" ALLO"ILI LI"!!8 XO.IT'BILITY, (Ple,b Po:l.at, P) OOIIOl1'ITY. (pi) RlaOTI'ITY w/..TIR RI&OTJ,¡TY l'IYDR001R801. >140 7. . no DO )i~O >2 - (12.5 no no ----~-~--~--~~-~-----~-----------~~~~--..~----------------_.._~------p~~~-- I' TOIICITY MIT&LS per SI-8" '1\81110 .g/L 81RIIK .I/L O'D"IO" .,/.. 081\0MIIM .I/L LI'D .g/L MIRCURY .,/L IILIJIUM .ø/L SIL'IR -g/L < o. Ot O. 1 < O. 01 <0. 5 <1. 0 <0.00' < O. 01 <0.5 5.0 '00. 1.0 5.0 &. 0 0.2 1.0 15, 0 Reaa I&I&RDOIS W&STI: 10 CO""I,fS: --~-~~~~---------------_.*-~~- "ALYSTS I š;~---~-- Labor,tor, Maaag.r page 1 ot , SCI-îNNEC JUN 1 ? 2DOl~. #7 ·' T RECEIVED J U L - 1 1988 Alaska. Oil & Gas Cons. Commission . Anchorage " ARCO Alaska, I ) legal Department Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 901 265 6553 G ~~ ~~ ') ) William T. Christian Senior Attorney April 19, 1988 Mr. Richard Thiel U.S. Environmental Protection Agency Region X 1200 Sixth Avenue Seattle, Washington 98101 Dear Mr. Thiel: We appreciate your meeting March 30th with ARC a Alaska, Inc. regarding annulus injection and the definition of Class II fluids. As agreed, the following is our s.ummary of the issues. 1) Annulus injection: The current EPA view on permis- sible annulus injection activity is set forth in the November 24,1987 memorandum from Paul Baltay to Dick Thiel (copy attached). That memorandum states that the annul us of a s i ngl e well may be used to inject appro- priate fluids derived from wells other than the one used for injection. It states: "This decision is not affected by whether the muds are produced in drilling of one or several wells or whether they are placed into. . . the annulus all at once or over a period of time." As you know, Horth Slope operators use annulus injection to dispose of both pumpable drilling muds and reserve pit fluids. Reserve pit fluids consist of drilling muds and snow melt and rain water. It was your view in the meeting that reserve pit fluids may appropriately be disposed of by annular injection provided that hazardous wastes are not included. An earlier letter written by EPA's Robert Surd to Dennis Kelso (copy attached) does not wholly agree with the views taken in Baltay's November 24th memorandum. To the extent that that earlier letter expresses views inconsistent with the November 24th memorandum, espe- cially that injection into an annulus is limited to fluids derived from that same well, it is superseded. 2) Cl ass I I Fl u ids: Wi th respect to the nature of fluids which may be injected into class II wells, EPA's latest views are expressed in the July 31, 1987 ñ î!i\~ 1] !~i 200-1 f.,,,,1 ~.. ~ '- l... li i':,\ '-' -.. "~~ ARCO Alnkl, Inc. Is I Subsldilry of AllanticRlchfleldComplny . , ) Mr. h )ðrd Thiel April ~.i, 1988 Page 2 '~ ) Guidance Memorandum from Michael B. Cook to Regional Water Supply Branch Chiefs (copy attached). That memorandum states that four kinds of fluids are eligi- ble for injection into Class II wells. These four categor.ies include brines and other fluids brought to the surface (i.e., used in wells) in connection with oil and gas production (produced waters, brines, workover fluids)¡ and these fluids used on site when mingled with fresh water so long as used for purposes integrally associated with oil and gas production. We asked whether reserve pit fluids, which principally conta in dri 11 i ng muds and snow mel t and other surface precipitation qualify under this definition. The answer ;s yes, so long as hazardous wastes are not i ncl uded. I f you have comments or note d i screpanc i es in the views expressed above, please get in touch with me. Again, we appreciate your efforts to clarify this matter. Very truly yours, ~ cLt5~~ William T. Christian encl. cc: R. Burd C. V. Chatterton L. Dietrich B. Fristoe D. Ke 1 so A. Ewing RECEIVED .III '- - 1 1988 Alaska Oil & Gas Cons. Commission Anchorage . .~ SCJ~VNNtèJ--, JUN 'í: '{ ~)r¡ ·ì 7 1£-17 o TE-I?J. ii !~. l' r,) 200'" ~-~\{_.,oIt\I!,.,~~\t¿,:..::_.,) ~) ~.iÞ~ ..L J : '-Š' lD-08(WSAK .-\ 1£-16 ~ 1£ -21-G/ 1 D-OJ 1£-19-G/ 1£-20 1£-18 1£-08 ~ 1£-11 1£-101 1C-03 --o! ¡- 1 B-06 ~ CPF-1A 18-04 11 1 e - ~ W.SAK ~ o S.W.P.T.'1 ~ o 40 fC-OB So 2 3 4 So WEST SAK 01 & o ( 1B-fO-G/ 18-09-j ~\ f KIC 1B-ll-G/ f-- I I I . o o o I 33 . ) ./ 1H-OB / ~) ~ 1 ç- _(17 ~ IF-14 ~ ., ~ 5 I IF-06 , ~ 1 A -04 lA-14 ~ ý fA -03 1G-12 ~ ,........1'" JG-11 #6 ~\~'é.O sr,<fl': 0'" ~15' ~. ft ~ " _ "Z. -~W D ~ o 't" \~ O~ 1-1: '\~ "'¿ PRO,,\~0 '.¡ Il) ) U,S. t:r'~VIRONMENTAL PROTECTION AGit.."NCY REGION 10 1200 SIXTH AVENUE SEATTLE, WASHINGTON 98101 HOV 4 t~6 REPLY TO A TTN OF: MIS 409 James D. Weeks, Manager Kuparuk Operations P.O. Box 100360 Anchorage, Alaska 99510-0360 RE: Termination of EPA Emergency Permits at the Kuparuk River Unit (Kuparuk Fi e1 d) Dear Mr. Weeks: The Alaska Oil and Gas Conservation Commission issued the Arco Alaska Incorporated an Area Injection Order No.2 for the Kuparuk River Unit (Kuparuk Field) on June 6, 1986. Therefore, the following EPA Emergency Permits for 'injection wells are terminated in accordance with 40 CFR 144.40: AK-2R0086-E through·AK-2R0097-E AK-2R0107-E through AK-2R0214-E AK-2R0219-E through AK-2R0233-E AK-2R0240-E AK-2R0242-E AK-2R0259-E through AK-2R0270-E AK-2D0103-E and AK-2D0104-E. Also, EPA rule authorization under either 40 CFR 144.21 or 40 CFR 144.22 for other existing injection wells is terminated. Your cooperation with EPA's Underground Injection Control Program and during transition of the Program to the state is appreciated. Sincerely, ìLLJßr~ Robert S. Burd Director, Water Division cc: C. V. Chatterton, AOGCC SC;\NNEG J UN 1 ìi] 20D~· #5 ) ) ARCa Alaska, .. ) , Post Office L-..))( 1 00360 .. Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 14, 1986 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Chatterton: r::ö:'/,[~ .... 1l~ ~'I:"'--'-¡' ., . . ... .',:J___+___\ ~ ~ 1'---" --r¡ , I : -1-' UT-: ..:,::'f,'-r-¡ i" fE:·(;Hì-: ,·······',,·····./·'I;j-I .'.: rr II Ie:, ~"¡I f'll ~ , : ".,.~...,.....~..._,...".,'......__......,' ,I ARCO Alaska Inc. requests an amendment to Rule No. 3 of the Area Injection Order No.2 for the Kuparuk River Unit. We are requesting Rule No. 3 be amended to include the following statement: "Pumping of excess non-hazardous fluids that are developed solely from well operations, or necessary to control the fluid level of Reserve Pits, into surface/production casing annuli is exempt from the above requirements". This language is consistent with Area Injection Order No. 4 . These fluids will be pumped into the authorized injection strata as set out in Rule No.2. Sound engineering practices will be maintained and the procedure will not result in any increased risk of fluid movement into any underground source of drinking water. Sincerely, fq ~.Á~~ R. A. Ruedrich Drilling Manager RAR/MBW/mal L01 10-14-86 cc: P. Hellstrom - ATO 2030 ·<,..~,;L\ \~ '7~ '\ (\ P. ç\ ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany ~Ct~NNEL'1 JrUN 1 ~1 2004 ARca Alaska, h.~. .~ Post Office bv..c 100360 Anchorage, Alaska 99510-0360 Telephone 901 216 1215 J ~~ ~~ June 6, 1986 Mr. L. C. SMith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive .Anchorage, AK 99501 Dear Commissioner Smith: RE: Kuparuk River Unit, Area Injection Order Application, Addendum The following information, as requested in your meeting on June 5, is submitted as an Addendum to the Kuparuk River Unit Area Injection Order Application. It is requested that the Ugnu Sands enhanced oil recovery interval, for purposes of this application, be defined as the hydrocarbon bearing interval between 3145 feet measured depth and 3640 feet measured depth in the ARCO We s t Sa k S tat e N u m b e r 1, and 1 ate r ale qui val e nt s . Please contact either Julie Athans (265-1345 or me (263-4212) if you have any questions. Sincerely, /Í1t2A--~ T. M. Drumm Operations Coordinator T~1D:fl (0057) cc: C. Chatterton, AOGCC R~(1F~\ILr) . ::.... "," r..... I ,. Å._ '..' Ie< ¡ ~\ j 1" ;'; "I CiSf" '0<1 L} i ,) '.J ~~") Q 1'\; ~'\. 2\!< 1. ~::: i L ,.~'' :~,S 1'--0"'" SC/1NlNE[: ",fUN J '7 2004 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany #4 ARca Alaska, .. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~~ ~~ fro K'- June 4, 1986 ~1 r. L. C. S m i t h Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Commissioner Smith: .RE: Kuparuk River Unit, Area Injection Order Application Addendum The enclosed information, as requested in your May 23 and June 3 phone calls to me, is submitted as an addendum to the Kuparuk River Unit Area Injection Order Appl ication. The following information is enclosed~ 1. List of KRU injection wells permitted by EPA 2 . Lis t 0 f K R U i n j e c t ion we 1 1 s aut h 0 r i zed by r u 1 e by 'E P A 3. Specifics on Colville Group/Sagavanirktok Formation disposal zone 4. Specifics on Ivishak Formation disposal zone 5. Legal description of the current KRU participating area and 6. Replacement sentence for the last two sentences in Section I, page 19. Concerning items #3 and #4 above, ARCO requests the flexi- bility to redefine the specific injection zones within the scope of the existing geologic information submitted in the original application, upon submission of acceptable data to the Commission. The specific injection zones given in this addendum are sufficient for future injection activities, to the best of our current knowledge. Please contact either Julie Athans (265-1345) or me {263-4212) if you have any questions. -r- /JlcuL ct)~ T. M. Drumm Operations Coordinator Enclosures ::.;;,c C~ ~J IA i 1;:: ~'~ . j n ¡ ~ I,: .:! LJ? 0 rn """ ¡/-\ìð'\:lO'",_:..) ....¡Un ..:... ., '- '-'"1 cc: C. Chatterton, AOGCC ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany ''\ ) ) KUPARUK EPA INJECTION PERMITS Well UIC Permit Number Well UIC Permit Number Well UIC Permit Number I L-O I AK-2ROI12-E 2C-07 AK-2ROI44-E 2U-16 AK-2ROI90-E IL-03 AK-2ROI13-E 2C-08 AK-2ROI45-E 2V-08 AK-2R0097 -E I L-05 AK-2ROI14-E 20-02 AK-2ROI46-E 2W -02 AK-2ROI91-E IL-07 AK-2RO 115-E 20-04 AK-2ROI47-E 2W-04 AK-2ROI92-E I L-16 AK-2RO 1 08-E 20-05 AK-2RO 148-E 2W -05 AK-2ROI93-E 1 Q-O I AK-2ROI09-E 20-07 AK-2ROI49-E 2W -08 AK-2ROI94-E IQ-02 AK-2ROI16-E 20-10 AK-2ROI50-E 2W -09 AK-2ROI95-E IQ-07 AK-2ROI17-E 20-11 AK-2ROI51-E 2W-I0 AK-2ROI96-E IQ-08 AK-2ROI18-E 20-14 AK-2ROI52-E 2W-14 AK-2ROI97-E I Q-ll AK-2ROI19-E 20-16 AK-2ROI53-E 2W-16 AK-2ROI98-E 1 Q-12 AK-2ROI20-E 2E-09 AK-2ROI54-E 2X-Ol AK-2ROI99-E I Q-13 AK-2ROI21-E 2 E-l 0 AK-2ROI55-E 2X-02 AK-2R0200-E I Q-14 AK-2ROI22-E 2 E-12 AK-2ROI56-E 2X-03 AK-2R0201-E I R-03 AK-2RO 123-E 2 E-13 AK-2ROI57-E 2X-04 AK-2R0202-E IR-08 AK-2ROI07-E 2 E-14 AK-2RO 158-E 2X-05 AK-2R0203-E IR-I0 AK-2ROI24-E 2F-Ol AK-2RO 159-E 2X-06 AK-2R0204-E IR-13 AK-2ROI25-E 2F-02 AK-2R0160-E 2X-07 AK-2R0205-E 1 Y -01 AK-2ROI26-E 2F-03 AK-2RO 161-E 2X-08 AK-2R0206-E I Y -02 AK-2R0086-E 2F-04 AK-2ROI62-E 22-02 AK-2R0207-E 1 Y -07 AK-2ROI27-E 2F-13 AK-2ROI63-E 22-03 AK-2R0208-E I Y -08 AK-2R0087-E 2F-14 AK-2ROI64-E 22-06 AK-2R0209-E I Y -10 AK-2ROI28-E 2F-15 AK-2ROI65-E 22-08 AK-2R0210-E I Y -12 AK-2R0088-E 2F-16 AK-2ROI66-E 22-09 AK-2R0211-E IY-13 AK-2ROI29-E 2G-Ol AK-2ROI67-E 22-11 AK-2R0212-E IY-15 AK-2R0089-E 2G-03 AK-2ROI68-E 22-14 AK-2R0213-E 2A-0 1 AK-2R0090-E 2G-05 AK-2ROI69-E 22-16 AK-2R0214-E 2A-02 AK-2R0091-E 2G-07 AK-2ROI70-E 3 A-06 AK-2R0259-E 2A-03 AK-2R0092-E 2G-I0 AK-2ROI71-E 3A-07 AK-2R0260-E 2A-04 AK-2R0093-E 2G-12 AK-2ROI72-E 3A-14 AK-2R0261-E 2A-05 AK-2R0094-E 2G-14 AK-2ROI73-E 3A-15 AK-2R0262-E 2A-06 AK-2R0095-E 2G-16 AK-2ROI74-E 3B-02 AK-2R0224-E 2A-07 AK-2R0096-E 2 H-O 1 AK-2ROI75-E 3B-05 AK-2R0225-E 2B-05 AK-2ROI30-E 2H-02 AK-2ROI76-E 3 B-1 0 AK-2R0226-E 2B-06 AK-2ROI31-E 2H-03 AK-2RO 177-E 3 B-16 AK-2R0227 -E 2B-07 AK-2ROI32-E 2H-04 AK-2RO 178-E 3C-02 AK-2R0220-E 2B-08 AK-2RO 133-E 2H-13 AK-2ROI79-E 3C-0 5 AK-2R0221-E 2B-09 AK-2RO 134-E 2H-14 AK-2ROI80-E 3C-07 AK-2R0222-E 2B-I0 AK-2ROI35-E 2H-15 AK-2ROI81-E 3C-12 AK-2R0223-E 2B-ll AK-2RO 136-E 2H-16 AK-2ROI82-E 3F-04 AK-2R0263-E 2B-12 AK-2ROI37-E 2U-03 AK-2ROI83-E 3F-07 AK-2R0264-E 2C-0 1 AK-2ROI38-E 2U-04 AK-2RO 184-E 3F-12 AK-2R0265-E 2C-02 AK-2RO 139-E 2U-05 AK-2ROI85-E 3F-16 AK-2R0266-E 2C-03 AK-2RO 140-E 2U-07 AK-2ROI88-E 3J-05 AK-2R0267 -E 2C-04 AK-2R0141-E 2U-09 AK-2R0186-E 3J-08 AK-2R0268-E 2C-0 5 AK-2R0142-E 2U-11 AK-2R0187-E 3J-13 AK-2R0269-E 2C-06 AK-2R0143-E 2U-14 AK-2ROI89-E 3J-16 AK-2R0270-E CPF-1 AK-200 1 04-E çJ?~;?\j 11-_AKn3~0.f ~LTIO] ~"'\~,..J"-~ \:'~ ~ c~, c', l.' "- '........ w he {' e '5 tvStv.- oj ~ ) '.\ ") KUPARUK INJECTION WELLS - AUTHORIZED BY RULE Well Well 1 A-07 1 E-23 1 A-09 1 E-24 1 A-II 1 E-27 1 A-12 lE-30 lA-13 1 F-02 1 A-14 1 F-04 1 A-15 IF-05 1 A-16 1 F-08 1 B-09 IF-I0 1 B-1 0 1 F-ll 1 B-ll IF-13 lC-06 IF-15 1 C-09 1 G-02 1 C-l 0 IG-03 10-02 IG-04 10-05 1 G-05 10-06 IG-06 1 E-O 1 1 G-09 1 E-04 1 G-14 1 E-05 1 G-16 1 E-O 9 2V-Ol 1 E-l 0 2V-02 1 E-13 2V-03 1 E-14 2V-04 1 E-16 2V-05 1 E-19 2V-06 1 E-21 2V-07 S(;!-\NNEL,' JON 1 ? 2DD4 ¡,-'r· j\r:\~;;'H:,:r '" '~1 ~I r~: 20(\ 1 ,;),\."cir\ï~~~ d!!,.,..I.' <HJb\1 .L \ _, .,i" The uppermost portion (3390' - 3406' md, Attachment 1) o£ the Lower Ugnu in the CPF-3 and northern CPF-l areas, contains some hydrocarbons. InJection £or disposal will only occur in the areas non-productive o£ and isolated £rom hydrocarbons. There are su££icient disposal intervals and adequate vertical permeability barriers (mudstones) in the Lower Ugnu to allow disposal in the Lower Ugnu throughout the KRU. The Lower Ugnu Sands, £or the purpose o£ this application, should be de£ined as the interval between 3390 £eet and 3640 £eet measured depth in ARCO West Sak State No.1, and its lateral equivalents. This package o£ sands is reasonably correlative throughout the KRU, however, individual sand bodies within the Lower Ugnu are di££icult to trace £or more than several miles. This is due to their non-marine, £luvial origin. It is requested that all o£ the Lower Ugnu Sands (see Attachment 1) be designated as a potential disposal zone £or purposes o£ the Kuparuk River Unit Area InJection Order Application. The Lower Ugnu Sands represent the deepest o£ the shallow aqui£ers in the Kuparuk River Unit with rock properties suitable £or inJection. Various portions o£ the Lower Ugnu are already in use as disposal intervals in CPF-l, CPF-2 and the West Sak Pilot. Horizons shallower than the Lower Ugnu are potential inJection intervals, but it is desirable to con£ine inJection to as limited a stratigraphic interval as possible. SECTION G -- COLVILLE GROUP/SAGAVANIRKTOK FORMATION 6/4/86 ADDENDUM ) ) ARca WEST SAK RIVER STATE 1 SEC. 2, T.11N., R.10E., UM GR LL8 50 100 1 10 100 ~ SCA~H\~Ef) .JUN :~ ? 2004 + K-12 WEST SAK SANDS + + LOWER UGNU SANDS REQUESTED INJECTION INTERV AL t UPPER UGNU SANDS t 'I~ ') ....$ ? / "'. '" I 1 ) ¡ > 1'- t > ? ... 4000 '- ;S ~ ~, ~ ~ ~ ~ 3800 '- 3600 '- "I ~ - 3400 '- ~ ~ ...- t .? ~ 3200 '- .:- ~ ~ ) ) ) SECTION G -- IVISHAK FORMATION 6/4/86 ADDENDUM The Ivishak in the KRU is a £ormation that may be used in the £uture as a disposal zone. It is requested that porous and permeable intervals o£ the Ivishak Formation be designated as potential disposal zones. These intervals appear to have su££icient permeability to allow inJection. The Ivishak disposal zones~ £or purposes o£ this application~ should be de£ined as the interval between 8370 £eet and 8800 £eet measured depth in the ARCQ-BP Ugnu #1~ and its lateral equivalents. cc.'(("" r~iji.':JI:-~-i' H t"n 011 I')· 20r ~ \.)vj-~ö··j¡j'\j~t...., .J U hi ,£. ,I _ ",.'1" TI0N-R8E-UM See. 1 See. 2 See. 3 See. 4 See. 5 See. 6: SE/4 See. 7: NE/4, SE/4 See. 8 See. 9 See. 10 See. 11 See. 12 See. 13: NE/4, NW /4 See. 14: NE/4, NW /4 See. 15: NE/4, NW /4 See. 16: NE/4, NW /4 See. 17: NE/4, NW /4 TI0N-R9E-UM See. 1 See. 2 See. 3 See. 4 See. 5 See. 6 See. 7 See. 8 See. 9 See. 10: NE/4, NW /4 See. 11: NW / 4 See. 18: NE/4, NW /4 ) ') Kuparuk Partieipating Area Kuparuk River Unit Agreement Sta te of Alaska (Effeetive June, 1985) TI0N-RI0E-UM See. 6: NE/4, NW /4 TIIN-R8E-UM See. 1 See. 2 See. 3: NE/4, SE/4 See. 10 See. 11 See. 12 See. 13 See. 14 See. 15 See. 16: NE/4, SE/4 See. 21 See. 22 See. 23 See. 24 See. 25 See. 26 See. 27 See. 28 See. 29: SE/4 See. 32: SE/4, SW /4, NE/4 See. 33 See. 34 See. 35 See. 36 1 f~r'I·~r~~fi\~rc.:f··· ~~ ~M '1 i) 20f' fi "0 ~ ò\~ \" \:: /1;.. .".;,' Cblj.¡,J. ~ ,;:, ,JI.. i:. ... .'~.....' '"I' TIIN-R9E-UM See. 1 See. 2 See. 3 See. 4 See. 5 See. 6 See. 7 See. 8 See. 9 See. 10 See. 11 See. 12 See. 13 See. 14 See. 15 See. 16 See. 17 See. 18 See. 19 See. 20 See. 21 See. 22 See. 23 See. 24 See. 25 See. 26 See. 27 See. 28 See. 29 See. 30 See. 31 See. 32 See. 33 See. 34 See. 35 See. 36 ) ) Kuparuk Partieipating Area Kuparuk River Unit Agreement Sta te of Alaska (Effeetive June, 1985) TIIN-RI0E-UM See. 1 See. 2 See. 3 See. 4 See. 5 See. 6 See. 7 See. 8 See. 9 See. 10 See. 11 See. 12 See. 13 See. 14 See. 15 See. 16 See. 1 7 See. 18 See. 19 See. 20 See. 21 See. 22 See. 23 See. 24 See. 25 See. 26 See. 27 See. 28 See. 29 See. 30 See. 31 See. 32 See. 33: NE/4, NW /4 See. 34: NE/4, NW /4 See. 35: NW /4 2 SC¡\N~\!EC: JUN :1 "1" 2c![J,~ ) ') Kuparuk Partieipating Area Kuparuk River Unit Agreement State of Alaska (Effeetive June, 1985) TIIN-RIIE-UM See. 5 See. 6 See. 7 See. 8 See. 17: NW/4, SW/4, NE/4 See. 18 See. 19 See. 20: NW /4 TI2N-R8E-UM See. 1 See. 2 See. 11 See. 12 See. 13 See. 14 See. 23 See. 24 See. 25 See. 26 See. 35 See. 36 TI2N-R9E-UM (eontinued) See. 21 See. 22 See. 23 See. 24 See. 25 See. 26 See. 27 See. 28 See. 29 See. 30 See. 31 See. 32 See. 33 See. 34 See. 35 See. 36 TI2N-R9E-UM See. 1 See. 2 See. 3 See. 4 See. 5 See. 6 See. 7 See. 8 See. 9 See. 10 See. 11 See. 12 See. 13 See. 14 See. 15 See. 16 See. 17 See. 18 See. 19 See. 20 T12N-R10E-UM See. 5 See. 6 See. 7 See. 8 See. 9: NW /4, SW /4 See. 15: SW /4 See. 16: SE/4, SW /4, NW /4 See. 17 See. 18 See. 19 See. 20 See. 21 See. 22 See. 23: SW /4 See. 25: SE/4, SW /4- See. 26 See. 27 See. 28 See. 29 See. 30 See. 31 See. 32 See. 33 See. 34 See. 35 See. 36 3 Ç;"rl" i\f!\,H.\.~It:I'· ~~ P\~ li L') ?np., ~y·~.,,¿r~u:jr~~...,.,.i \J\'..,Ij~, .', I'; 1..1),:/1' ) ) Kuparuk Participating Area Kuparuk River Unit Agreement State of Alaska (Effective June, 1985) TI2N-RI1E-UM Sec. 31 TI3N-R8E-UM Sec. 12: SE/4 Sec. 13: SE/4, SW /4, NE/4 Sec. 23: SE/4, SW /4, NE/4 Sec. 24 Sec. 25 Sec. 26 Sec. 34: SE/4, NE/4 Sec. 35 Sec. 36 TI3N-R9E-UM Sec. 3: SW /4 Sec. 4 Sec. 5 - Except that portion containing USS4275 Sec. 6: SE/4 Sec. 7 - Except that portion containing USS4275 Sec. 8 - Except that portion containing USS4275 Sec. 9 Sec. 10 Sec. 15 Sec. 16 Sec. 17 Sec. 18 Sec. 19 Sec. 20 Sec. 21 Sec. 22 Sec. 25- Sec. 26 Sec. 27 Sec. 28 Sec. 29 Sec. 30 Sec. 31 Sec. 32 Sec. 33 Sec. 34 Sec. 35 Sec. 36 4 1¡·-'f'~"/) ~"\~iLr" qJ!\f 1: r-'·, . ,~y" \E~H~I!= ... ,h II,; .: ? 2C![lt ) ) SECTION I 6/4/86 ADDENDUM (Replacement sentence £or the last two sentences o£ original submission) All casing is cemented and tested in accordance with 20 AAC 25.412, £or both newly drilled and coverted inJection wells. I!';~N :/"-;H'¡~~ #3 , , \¡ ) '~ ,), ) Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of ARCO ALASKA, INC. for an Area Injection Order for the Kuparuk River Unit in the Kuparuk River Field. The Alaska Oil and Gas Conservation Commission has been requested, by letter dated April 22, 1986, to issue an order for area inj ection to provide authorization for utilizing service wells permitted in accordance with 20 AAC 25.005 or 20 AAC 25.280 to inject fluids underground for purposes of enhancing oil recovery from the Kuparuk River Unit in the Kuparuk River Field, and disposal of non-hazardous oil field fluids into Cretaceous and Tertiary strata. Parties who may be aggrieved if the referenced order is issued granting the request are allowed 15 days from the date of this publication in which to file a written protest stating in detail the nature of their aggrievement and their request for a hearing. The place of filing is the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501. If such a protest is timely filed, a hearing on the matter will be held at the above address at 9:00 AM on June 18, 1986 in conformance with 20 MC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433, after May 28, 1986. If no such protest is timely filed, the Commission will consider the issuance of the order without a hearing. ~ ¿j, dAkLJ Harry W. Kug¡:7 Commissioner Alaska Oil and Gas Conservation Commission Publication date: May 12, 1986 t~Ct~~¡~~E[- ~.Hjr~1 1: ? 20[)t:) TH~ ANCHORAGE TI~ P.o. BOX 40 ANCHORAGE, ALASKA 99510-0040 ROOF OF PUBLICATION K OIL & GAS CONSERVATION COMM 001 PORCUPINE DRIVE NCHORAGE, AK 99501 AROLINE BRIGHT , BEING DULY WORN, ACCORDING TO LAW DECLA~ES: HAT SHE IS THE LEGAL CLERK OF THE NCHORAGE TIMes, A DAILY NEWSPAPER UBLISHED IN THE TOWN OF ANCHORAGE N THE THIRD JUDICIAL DIVISION, TATE OF ALASKA, AND THAT T~E OTICE OF.......................... PO: AO-0855.59 COpy OF WHICH IS HERETO ATTACHED, IAS PUBLISHED IN......~.~~......... IF THE ANCHORAGE TIMES. ,EGINNING ON................~...... :NOING ON........~................. 1 ISSUES 05/12/86 05/12/86 'HE SIZE OF TkIS AD WAS.....~...... 67 LINES SIGNED.......... -¿~~ 'HE PRICE OF THIS AD IS............. $ 21.44 rHE AD NUMBER IS.................... 2343527 $UBSCRIBED AND SWGRN rc BEFORE ~E THIS................... 12 DAY OF MAY,1986 NOTARY PUBLIC OF lHE STATE OF ALASKA (' i-J ~ ____~~nf!!;L-~- J MY COMMISSION EXPIRES............... /()-- / '7 - s-ri ~---~-~-~~--~-~~-~- N.O.......t. lçe. ~f. .·.F-'IJ. ~IIF. ~:e,~.~I.~r..';'.:;.'.:::.w.'.·..·.:j sTtàeo( ALAS"KA....':' i.":! . , . .. "A1aska QU.an:lGas .... .. .... .1 ....' conser~atl~n7°rrl'!'lsslb!1i/1:i. R E :.The ap)Hcatlbn of .AR,ç:qj ALASKA"IN(:;,for¡an Ar~all'!1~:11 lectIOI')Or~er. far ·the ·:~upar:;",k,: Rlvør:'Unl~ll'I;the, KUP.c;i~~:k:) Rlv~.r¡:::'eld,' .'.. .'. ............... ·.··,...1;' ,:....~ .Ttíe,.A'!as~b,'PII·,'!al'ld',GtiSI'G~~~·;:: servåtlon·'Cam.rr'llsslj)'\has.b.eenl~, I requested. by letter dated APrll. 22. 1986. to Issue an order for' area Inlectlon to provide' al)tho~ rlzatlon for utilizing servlc:e:' wells permitted In accordance:,' with 20 A,AC 25.005 or 20 AAC';; , . ~~~~~d %r WJ~~~s~~u~nn~~g~~: . Ing 011 recovery from the Kupa- ruk RMlr Unit In the Kuparlk' River FI"ld, and disposal of non'" hazardous 011 field fluids Into, Cretaceous an~ Tertiary str~ta~' Parties' wtlo -' may be ',ag·" . f¡lrs~~~Jf ~þgnW~:r~~~e~~~~~~ I " ~~;e ~~~~~dpJ6H~~h~nfr~~~t~~·~ . 'to fII\! d wrl'tten'p'r'atest statl~g,;. In 'detall,th&' natur" of thell' dO" grlevement \:Ind tt'l!!lr request" for a hearing, the place offll'l:lg I Is the Alaska 011 and Gas Con- servatlon' Commission. 300r Porcupine. 'Drive, Anchora~e. Alaska 99501; If such a protest Is' ~~~~r ~Ifldb~?~~~aóf~~e o&'J~: ' ~Q8d¡er~ aJo~~~~~~g: ~W~lló, . AAC 25.540, If a hearing Is to:be held. Interested' portles may ~1~~I~~':~~~f~~e~al¿~~ t~9~~~: 1 after May 28. 1986. If no' sUCh. protest .1$ timely flied. the Com-. . mission will consider the Is· suance of the order wlthout.Q heOrlng., i " . . , Isl Ha~rYcW.·Kugler: :. Comm'lsslo.ner .. .~," . ~~~~~~rllg~~~::'~ls'~'lan PQ: AO.08i.55~9 Pub: Moy 12,1986 RErF" ._~ MAY 1 4 1986 Alaska 011 & Gas Cons. Commission Anchoraga "1 r."J "nn¡l .L :1 ¿Llti", #2 ARCO Alaska, 11"1\ Post Offi¿', -'o~ 'Q360· Anchorage, AI~sKa 99510-0360 Telephone 907 263 4509 ( ~~ ~,. J. D. Weeks Kuparuk Operations Manager April 22, 1986 I( 0 ~ 7- Mr. C. V . Chatterton 'Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchor age, AK 99501 RE: Kuparuk River Unit, Area Injection Order Application Dear Mr. Chatterton: Enclosed is the Kuparuk River Unit area injection order application. ARCO Alaska, Inc. as operator of the Unit requests an area injection order be issued for current and future injection wells, as described in the application. The application was prepared in accordance with the recently revised Commission injection regulations. ARCO requests injection approval for two types of injection wells - fluid disposal and enhanced recovery. Three injection zones are included in the application - the Sagavanirktok/Colville, the Ivishak and the Kuparuk River Formations. The process associated with the transfer of authority from the EPA to the Commission affects both existing and new injection wells. Existing wells are authorized by permit and rule by EP A and those authorizations remain in place until a replacement permit is issued by the Commission. New injection wells (newly drilled or converted) require prior authorization under both EP A and AOGCC rules. A mechanism for permitting new injection wells after termination of the EP A program and prior to issuance of our area injection order under the new AOGCC rules is not clearly defined. ARCO proposes that in the unlikely event a new injection well is necessary during the interim period, the injection well be temporarily authorized by the Commission upon submittal of an acceptable sundry notice or drilling permit, pending issuance of the area injection order. ARCO requests the area injection order be issued as soon as possible. Please contact Mark Drumm (263-4212) or Julie Athans (265-1345), if you have any questions or require additional information. Your timely action is appreciated. D. Weeks Kuparuk Operations Manager Enclosure RECEIVED cc: L. Smith, AOGCC H. Kugler, AOGCC APR 2 3 1986 Aiaska on & Gas Cons. Commission Anchorage (Ç!: It' J' 11\ ~ jà.Uj"-~' . !I ~j ~ TI 1 ~"'I 2 0 0 II ~-'Vð-ìB~!R~[-:L) ~)j\Lll'~¡ 1 J_ ,> ,I,,' ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRlchfleldCompany I I I I I I I I I I I I ( t ~ ~ I'} Ir( 0 -Pt ~ KUPARUK RIVER UNIT AREA INJECTION ORDER APPLICATION I I I I I I RECEIVED APR 2 .3 1986 ..Alaska Oii & \;Iü.;" vJII¡). liommission :;;·.<.,V.., "..I Anchorage SC/\NNED JUN 1 7' 200~· " ~ ( KUPARUK RIVER UNIT AREA INJECTION ORDER APPLICATION T ABLE OF CONTENTS Section/Regulatory Cite Subject Page A. 20 AAC 25.460 Area Injection Order 1 B. 20 AAC 25.402(c)(l) Plat 2 20 AAC 25.252(c)( 1) C. 20 AAC 25.402(c)(2) Operators/Surface Owners 4 20 AAC 25.252(c)(2) D. 20 AAC 25.402(c)(3) Affidavit 5 20 AAC 25.252(c)(3) E. 20 AAC 25.402(c)(4) Description of Operation 6 F. 20 AAC 25.402(c)(5) Pool Information 8 G. 20 AAC 25.402(c)(6) Geologic Information 9 20 AAC 25.252(c)(4) I H. 20 AAC 25.402(c)(7) Well Logs 18 20 AAC 25.252(c)(5) I I. 20 AAC 25.402(c)(8) Casing Information 19 20 AAC 25.252(c)(6) l- J. 20 AAC 25.402(c)(9) Injection Fluid 21 20 AAC 25.252(c)(7) ¡ K. 20 AAC 25.402(c)( 1 0) Injection Pressure 28 20 AAC 25.252(c)(8) L. 20 AAC 25.402(c)(ll) Fr acture Infor ma tion 29 20 AAC 25.252(c)(9) M. 20 AAC 25.402(c)(l2) Formation Fluid 31 20 AAC 25.252(c)(lO) N. 20 AAC 25.402(c)( 13) Aquifer Exemption 33 20 AAC 25.252(c)(ll) O. 20 AAC 25.402(c)(l4) Hydrocarbon Recovery 34 P. 20 AAC 25.402(d) Mechanical Integr i ty 35 20 AAC 25.252(d) Q. 20 AAC 25.402(h) Wells Within Area 36 20 AAC 25.252(h) R. 20 AAC 25.450(a) Variance Request 37 8C;J\NK\HEUi ~JUN 11 ZDD!} Figure B-1 Figure G-1 Figure G-1a Figure G-2 Figure G-2a Figure G-3 Figure G-4 Figure I-I Figure J-l Figure J-2 Figure J-3 Figure J-4 Figure M-l :( { ,{ Kuparuk River Unit Area Injection Order Application List of Figures Title Plat Map Generalized Stratigraphic Section Type Log - Ugnu and West Sak Sands Structure Map of Top of Ivishak Sandstone Type Log - Ivishak Sandstone Stratigraphy of Kuparuk River Formation Top Kuparuk River Formation, Structure Map Wellbore Schematic Ugnu Water Analysis Seawater Analysis Gas Analysis Ivishak Water Analysis Kuparuk River Formation Water Analysis SC¿J;~~~~ED JUN 1 ~{ 2004· Page 3 14 14a 15 15a 16 17 20 24 25 26 27 32 I I I I I I I I I I I I I I 1 I I I I ( i , SECTION A Area Injection Order 20 AAC 25.460 ARCO Alaska, Inc., as operator of the Kuparuk River Unit (KRU), requests an area injection order be issued for current and proposed injection wells: 1) for disposal of fluids that are brought to the surface in connection with conventional oil and gas operations and comingled with non-hazardous waste fluids from facilities which are an integral part of production and operation, and 2) for the enhanced recovery of oil or gas. The area injection order is requested to encompass all lands within the boundary of the KRU. ARC a requests that the order allow ARCO to drill, operate, convert or plug and abandon wells within the KRU by filing Form 10-401 or Form 10-403. The Oil and Gas Conservation Commission may, in its discretion, issue an area injection order if certain requirements are met. The KRU injection operations meet the requirements of 20 AAC 25.460(a). Existing wells are described and identified by type. Injection wells are within the same field, are operated by a single operator and are used for other than hazardous waste injection. The cumulative effect of drilling and operating additional enhanced recovery injection wells will result in an increase in hydrocarbon recovery. The cumulative effect of additional fluid disposal wells has been reviewed and additional wells operated in accordance with Commission rules will not initiate fractures in the confining zone or cause migration into fresh water strata. Both types of injection wells will be drilled, constructed, operated, and abandoned in accordance with the Commission rules to prevent movement of fluids into freshwater strata. 1 SCA\I\~NED JUN 11 2004 I I I I I I I I I I I I I I 1 I 1 I I f ( Section B Plat 20 AAC 25.402(c)( 1) 20 AAC 25.252(c)( 1) Figure B-1 is a plat showing the location of all wells that penetrate the uppermost injection zone within the KRU boundary, i.e., the area covered by this area injection ord__er application. 2 SCAN~~IE[) JIUN 1 [it 2004 ( I I I I I SECTION C Operators/Surface Owners 20 AAC 25.402(c)(2) 20 AAC 25.252(c)(2) The surface owners and operators within the area of this area injection order and extending 1/4 mile beyond the boundary (excluding ARCO) are: State of Alaska Department of Natural Resources A ttn: Kay Brown 3601 CSt. Anchorage, AK 99503 I I I DEW Line Station Oliktok Department of the Air Force Attn: Major Worral 4700 ADS/DE Peterson Air Force Base, CO 80914 I I I Conoco, Inc. Attn: Rod Schulz 3201 C Street Sui te 200 Anchorage, AK 99503 Standard Alaska Production Co. Attn: Jean Parsons 900 E. Benson Blvd. P. O. Box 196612 Anchorage, AK 99519 'l 4 SC/\NNE() JUN 1. 6' 20n~ ß [ It \ 'I SECTION D Affidavit II 20 AAC 25.402(c)(3) 20 AAC 25.252(c)(3) Affidavit of Julie A. Athans STATE OF ALASKA THIRD JUDICIAL DISTRICT ! I, Julie A. Athans, declare and affirm as follows: 1. I am over 19 years of age. I am employed by ARCO Alaska, Inc. as an Environmental Coordinator. I have personal knowledge of the matters set forth in this affidavit. I 2. On /). fJ"Tli ,I ~ I 1986, the surface owners/operators listed in Section C were provided a copy of this permit application. I I I I ¡ DATED at Anchorage, Ii. pn ¡ ( , 1986. Alaska this d/~ day of ~¡;¿ Il- lJ~t~6 Julie A. Athans Subscr ibed and affir med cfpYVt- 2-/ , 1986. before me at Anchorage, Alaska on k~hÁ~ Notary Public in and for the State of Alaska My commission expires: f'-/3·-?'j 5 SCANNEL1 ~JUN 1 ê 2m)~, I I , ¡\ { ( SECTION E Description of Operation I 20 AAC 25.402(c)(4) f Current and proposed injection operations at the KRU are divided into two broad categories: r Subsection 1 - enhanced recovery, and Subsection 2 - disposal of fluids brought to the surface and comingled with non- hazardous waste fluids. 'I IP/ Subsection 1 Enhanced Recovery [ Enhanced recovery injection wells are used for the introduction of additional fluids into the oil reservoir to increase the ultimate recovery of oil. Three types of enhanced recovery injection wells are currently used: water injection, gas injection, and water-alternating-gas injection. (See the Kuparuk River Field, Full Field Water flood Project Testimony, May 23, 1984, for details.) Additional methods of enhanced oil recovery may be used in the future. Future injection wells will continue to be designed, constructed, operated and monitored to ensure the injection fluid is entering the oil reservoir. The Kuparuk River formation and the West Sak and Ugnu portions of the Colville/Sagavanirktok Formations are/may be used for enhanced oil recovery. I I I I ,I I Subsection 2 Fluid Disposal Produced water disposal wells are used for the disposal of produced water and other fluids generated during KRU operations. The produced water is water which is produced with the oil and separated from the oil and gas at the production 6 SCANNED JUN 1 1 20D4 r ~¡ \ \ Section E Continued I ( facilities. The remaInIng injection fluids are non-hazardous fluids generated by drilling and production operations. Central Production Facilities 1 and 2 have produced water disposal wells as does the West Sak pilot. An additional disposal well is planned for CPF-3. Future disposal wells will continue to be designed, constructed, operated and monitored to ensure the injection fluid is entering the injection zone. Injection is into shallow aquifers in the Sagavanirktok Formation and Colville Group. Injection may also occur in the Ivishak Formation. t II 1 I I, I. I \0.-. :( I I 7 i SCANNED ,JUN 1 '1 2004 ( I n \. SECTION F Pool Information ( 20 AAC 25.402(c)(5) r I The Kuparuk River Oil Pool, is defined by Rule 2 of Conservation Order No. 173 as the strata that are common to and correlate with the accumulation found in the Atlantic Richfield Company West Sak River State No. 1 Well between the depths of 6,474 and 6,880 feet, measured depth, or 6387.9 and 6793.9 feet, subsea. ~ The West Sak Sands is defined for the West Sak Sands Section 35 Project in Conservation Order No. 191 as the accumulation of oil found in Atlantic Richfield Company West Sak River State No. 1 Well between 3744 and 4040 feet, measured depth. I i or "" I I I ! 1 8 ~ct\~NED ~JUN 1 if 2004 f I { r I ,I' I { {, ( (. SECTION G Geologic Information 20 AAC 25.402(c)(6) 20 AAC 25.252(c)(4) Geologic information and figures on the zones used for injection in the KRU are included in three subsections: Subsection 1 - Colville Group and Sagavanirktok Formation; Subsection 2 - the Ivishak Formation; and Subsection 3 - the Kuparuk River Formation. I I 1- Subsection 1 Kuparuk River Unit - Colville Group and Sagavanirktok Formation I I I I Strata of the upper Colville Group and Sagavanirktok Formation comprise the late Cretaceous and early Tertiary shallow aquifers in the KRU area of the Alaskan North Slope. These aquifers occur between the base of permafrost and the K-12 marker as shown on the Generalized Stratigraphic section (Figure G-l). Significant amounts of low-gravity oil occur in two zones which ARCO refers to as the West Sak Sands and the Ugnu Sands. These zones are oil-bearing in the KRU between 2000 and 4500 feet subsea. A pilot project is currently producing oil from the West Sak Sands using the injection of hot, high-pressure water. Other pilot and experimental enhanced oil recovery processes for both West Sak and Ugnu involving, but not limited to water, gas, steam and/or chemical injection into these zones are planned to evaluate their commercial potential. In addition, the KRU is injecting waste water (principally produced waters from the KRU), into the lower Ugnu in a disposal well at the Central Production Facility No. 1 (CPF-l) in the southern KRU, updip from the oil accumulation. Similar injection activity occurs at CPF-2 and the West Sak pilot and is planned for CPF-3. ,I 9 8tA~~!~ED JUN 1. '12(10i~ ( I ,I ( It ( Section G Continued I I I I I I 1 I I The upper Colville Group in the KRU area corresponds to the West Sak Sand interval. The West Sak consists of fine-to very fine-grained silty sand with interbedded silt and clay, and has an average thickness of 300 feet in the KRU. Individual sand beds range from 2 to 40 feet in thickness. Core data show that sand porosity ranges from 25 to 35 percent and permeability ranges from 10 to 800 millidarcies. The top of the West Sak Sand occurs between about 1000 and 4500 feet subsea in the KRU, and dips ge"ntly to the east/northeast. Occasionally, additional thin-bedded, lenticular silty sandstones 10 to 20 feet thick are encountered in the 250 foot interval immediately below the West Sak Sands within the Colville Group (Figure G-l). For the most part, however, the underlying Colville Group consists of an impermeable mudstone and shale sequence over 2000 feet thick in the KRU. The Sagavanirktok Formation includes the Ugnu Sands and related overlying strata. The Ugnu Sands consist of fine-to-coarse-grained sand interbedded with siltstone, shale and minor amounts of coal. Total thickness averages 540 feet in the KRU. Individual sands range from 10 to 100 feet in thickness and average 30 feet thick. Core data indicate sand porosities between 25 and 40 percent and permeabilities from 200 to 3000 millidarcies. The top of the Ugnu Sands occur between 500 and 3700 feet subsea in the KRU and also dip gently to the east/northeast. The Sagavanirktok strata between the top of the Ugnu and the base of permafrost are similar to the Ugnu based on available data. I I The Sagavanirktok Formation contains laterally continuous mudstone and shale beds 10 to 50 feet thick which act as vertical permeability barriers. In addition, all stratigraphic intervals intersect the base of permafrost between 1300 and 1500 feet subsea in the western KRU. This isolates these formations from communication with surface waters. 10 SC!\NNE[,J> (JUN ~Ji. fi? 2004 { ( { '\ ~ Section G Continued ( ( Subsection 2 Kuparuk River Unit - Ivishak I \ I A major stratigraphic interval in the KRU area that may be utilized for future fluid injection is the Ivishak Formation of the Sadlerochit Group. This is the main reservoir in the Prudhoe Bay Field. To date, limited penetrations into this stratigraphic interval in the KRU have not discovered commercial hydrocarbon accumulations, and it is currently believed that trapping mechanisms are either nonexistent, insignificantly small, or undefinable by today's technology or the presently available data. I I I The Sadlerochit Group, late Permian to early Triassic age, is divided into three distinct geologic formations: the basal Echooka Formation, the Kavik Shale and the overlying Ivishak Formation (sandstone). The Sadlerochit Group overlies the Permian Lisburne Group and is over lain by, in ascending order, the Triassic Shublik, Sag River, and the Jurassic Kingak Shale Formations. Within the KRU the Ivishak varies in thickness from less than 550 to over 650 feet and the structural top varies from less than 8,000 to over 9,000 feet subsea. I I The Ivishak Formation is divided into four subunits on zones. Zone 4, the uppermost zone within the Ivishak Formation, consists of uniform fine-grained sandstone, occasional silty sandstone and minor mudstone beds. The interval thickness ranges from 180-230 feet; porosities range from 18-24%; permeability ranges from 1 md to +/- 100 md. Zone 3 consists of fine-medium grained sandstone/pebbly sandstone and conglomerate. The interval thickness ranges from 80-120 feet; average porosity is 17- 20%. Zone 2 is pdmarily a massive fine-grained sandstone up to 250 feet thick alternating with minor claystone/mudstone beds and pebbly sandstone. This interval has porosities up to 25% and permeabilities ranging from a few to 800 md. Zone 1 ranges from 80-120 feet in thickness. It is a very fine-grained sandstone interbedded with siltstone and mudstone. The porosity ranges from 16-20% with permeabilities of less than 30 md to 50 md. I In the KRU, the structural dip of the Ivishak is to the south and normal north-south and northwest-southeast trending faults occur with throws ranging from 50 feet up to I 11 ~CJ\NNE[) JUN 1 1 2004 I ( ( I ( I I I I I (- I '~, f , ( Section G Continued 200 feet (Figure G-2). A few small Sadlerochit closures of no significant size have been identified by seismic in the KRU. These closures are controlled by regional dip and structural displacement along faults. Tests from the West Sak Pilot 1-S well located immediately south of the Kuparuk Field indicates average total dissolved solids of 26,000 mg/l for the Ivishak Formation. References Jones, H.P. and Speers, R. G. (1976) "Permo-Triassic Reservoirs of Prudhoe Bay Field, North Slope, Alaska," in North American Oil and Gas Fields, AAPG Memoir 24, p. 23- 50. H. C. Jamison et al., 1980, "Prudhoe Bay A 10 year Perspective," in Giant Oil and Gas Fields of the Decade 1968-1978, AAPG Memoir 30, p. 285-314. Subsection 3 Kuparuk River Unit - Kuparuk River Formation I I '1 ! The stratigraphy of the Kuparuk River Formation is depicted in Figure G-3, which is a well log of water injection well 1A-13. The Kuparuk River Formation is divided into an Upper and a Lower Member which are separated by an erosional unconformity. Unit D is a siltstone unit and Unit B is a sequence of interbedded sandstone, siltstone and mudstone. The reservoir sands are found in the A and C Units, both of which are believed to have been deposited on a shallow marine shelf during Lower Cretaceous time. The C sands are quartzose, fine to coarse grained, poorly to moderately well sorted, bioturbated, containing trace to abundant amounts of glauconite and often cemented by siderite. The C sands average 23% porosity and about 175 md permeability. The A sands are quartzose, very fine to fine grained, and well sorted. The A sands average 23% porosity and about 75 md permeability. 12 ¡ ~Cl~N~\jED JUN 1 7 2004, l I ( I ( f ,t i{ ," ( Section G Continued I I I The Kuparuk River Field is a combination structural and stratigraphic trap. The depths shown on Figure G-4 are feet subsea, and faults have been omitted in order to simplify the structure. On the west, the field is bounded by an erosional unconformity which truncates the Kuparuk reservoir rocks. The approximate position of this truncation is shown by a dashed, scalloped line. The southern extent of the field is delimited by decreasing reservoir quality in the Kuparuk sands. To the north and east the limits of the oil pool are determined by the intersection of structural dip and the local oil-water contact. Several wells near the Kuparuk River Field oil-water contact have begun to produce reservoir water. Well 1B-8 is producing water with a total dissolved solids content of 24579 mg/l. Similarly, reservoir water from well lC-1 has 23494 mg/1 total dissolved solids. ( The confining interval above the Kuparuk River Formation consists of more than 2000' of Cretaceous shale. The lower confining interval is the Kingak shale, which exceeds 1500' in thickness. I'" ( I I I I 13 SC!~~N~~ED ~HJN 1 ['1 2004. U PP E R'::::~::; ;,~,:.::;. UGNU ::t!~~7~: ~:~Ji~5/ LOWER '::':;':;;'.::;;.:,:-:~ - - - - - - ~ UGNU ~~:6~~ (fJ ~ WS~St(T ~f~0~Q~l ~ ~ SANDS ~;:UÆf.: W ö o <t I- W a: o f I P[RIOD l ( { ,I \ I I .( f· { ( I I I > a: ct - I- a: W I- .~.. -( 1\ ~ Figure G-l GENERALIZED STRATIGRAPHIC SECTION LlTH- MARKU OLOGY DESCR"TION z o - ~ :i a: o u.. ~~I~.:· .:: ~ ~~ ;~~~:~:::~~~ ;;::'f~~~.~ ...." 0 ". .".,. (~))~( ~~~;{~~.: ~:f:~T~~\¡ }}~~t~~ BASE ~~:~::- PERMAFROST: Interbedded gravels, sands and shales. PERMA- .'.:'~.".;'; FROST ::.: :':~~'.;~:. ,~,,,.'. ~Q'- T-3 t~~1ti T-3: g:~~e~a~~~~e~~~ ~~~~~a~~da~~a~~~~rlain with inter- K-IS !!!!i;!! K-15: ~~~~~s~oa~O~:~~~~du~~~~~a~~c~~t~i~~~~Sìh~~l~~t~~~al. ~~:-J:¡ ~.:: ~~~~~~~d UPPER UGNU: Interbedded coarse to fine sands and shales. ~ o I- ~ a: ä > c( CJ c( en LOWER UGNU: Interbedded coarse to fine sands and shales. WEST SAK SANDS: Interbedded fine sandstones, siltstones, and clays. ;. ~..~::~~::;.~ W ..J ..J ~ o (.) ::.r:·.:7.·~.:=:·:: ',:':?··n::::·.r;:· - --, .. , K 12 %.~i3~ Based on data from:'ARCO West Sak River State #1 K-12 : Interlaminated silty mudstones and shales with minor silty sandstones. 14 ~", ~\I]t\~ 1 r;v 20n~~ to (r' j"t. \1\~ \ r ~ .'.'. H \'~I J. t, .- '0 I~.<)~,~:c,~t\~(.' \. :::.:.o:~L.....' ~ ,/,. ARCO ¡ ~ WEST SAK RIVER ST ATE 1 SEC. 2, T.11N., R.10E., UM GR LL8 50 100 1 10 100 ~ ~ I t .., ,-::::> t 3200 '- ~ ~ ~ UPPER UGNU > ~ SANDS t ? ( ? ~ t 3400 '- ~ I " ..-:!l: ¡ r ~ LOWER UGNU I SANDS ~ J 3600'- ~ > + \- ~ 1- ~ ? t 3800 I- /' > WEST SAK SANDS SC.f\NNEI.) JUN .~ ? 2.0nl~ 14a + K-12 ? '( Figure G-la l 1 [ [ ( I I" [ [ { (- { [ [ I I ( If 4000 '- - ----.---------.~~---~-------. I- 0" f.I1 Cl > z Z' rTi V ~ ~ ~.;:..:b =,jj N c::J ~ ..L;;Ð o Gamma Ray 150 1 Resistivity ~~.1~ {, . I. ~ ~ T4;! < ~____Jj~:~; ..._,,"'''''' - - ....-~ ~ ~ \ "----" 1000 Figure G-3 Subsea Inl.,- Unit Uem- Kuparuk River Field Deplhsva' ber D) Kuparuk River Formation We1l1A-13 C-4 ... C-3 CD ,~-+-~ a.. C a.. 6000' :) C-2 -r¡. ".ß'. ¡;: (~ --> if --.. J! Shallow -.......-. i~t¡i ~ . . p== ~þ C-1 - 6100' B A-6 --2 _ A-5 6200' - - 6300' A-4 A A-3 ... CD ~ o -J Ii Sandstone ~ Interbedded Sandstone, rææJ Siltstone, and Mudstone ~ Siltstone D Mudstone · ~ Glauconite gg Siderite Cement -"- Erosional Unconformity ,.s900- -,...600\t -1 ~ - ...'ô\()'u _ _,6?,OØ .. ~OO _...6 _ _töð,()O- Q()- -:õf:J Kuparuk River Field Structure Map Top Kuparuk River Formation ~-- -, ~ f ~ ~ ~ ~ , ""II " ~1Io.. FIGURE G-4 ~ f'V C) Cj d~ ,~\ c z !' ~t". -\B ,¡ ö :> =;? z m I- ....¡ I J Truncation Of Kuparuk Lower ~ Member ~ ,.J; -------------------- I [ I I 1 I I I Ii ~ ( SECTION H Well Logs 20 AAC 25.402(c)(7) 20 AAC 25.252(c)(5) All openhole logs from wells in the KRU are sent to the Commission as the logs are completed. Type logs for the KRU are included as Figures G-1 and G-3. , I I" I I I I I I I 18 SCAN~~E[) ,JUN ] t' 200L~ [ I I ,I I I I I I ( f I I i( { SECTION I Casing Information 20 AAC 25.402(c)(8) 20 AAC 25.252(c)(6) Typical wells are cased as shown in Figure I-I. Future West Sak development wells will be cased similar to Figure 1-1 with the exception of the surface casing, which will be eliminated. API casing specifications are included on each drilling permit application. All casing is cemented in accordance with 20 AAC 25.252(b) and tested in accordance with 20 AAC 25.030(g) when completed. In wells converted to injection, the casing is retested in accordance with 20 AAC 25.412(c). I I I I I 19 SCÞ~NNED JUN 1 I'ß 2DO~~ I ( I I I r I I I .1 I ( I I I I I I I ( Figure I-I ( WELL BORE SCHEMA TIC 'q' [J:(): Q -4 ....... ~-4 L L ~ . ~~ ~ // L.. . ;¿u "'t1h-.l ---- - OrftlllMll tVt' -- - Çonduotor ...JJt $urflOt CISing_. "00' MD ~t10\¥' blst of Wtst SIk ttsttd inttrni111 to '000 PSI Produotion Clsing_.~ ~1ow bllt of Kuptruk ttst.d inttrna 11\1 to 3SOO PS I 5{;t:\NNED JUN 1 Ii?) 2004 I [ I I I I I I ( (' SECTION J Injection Fluid 20 AAC 25.402(c)(9) 20 AAC 25.252(c)(7) The injection fluid for the two types of injection at the KRU are: 1) water and gas for enhanced recovery, and 2) fluids brought to the surface and comingled with non- hazardous waste streams for disposal wells. Subsection 1 Enhanced Recovery A. Type of Fluid - water. Analysis of Composition of Typical Fluid - (Kuparuk River Formation) Figures J-1, J-2, and M-l and, (West Sak Sands) Figures J-2, J-4. ( [ I [ I I I I I Source of Fluid - (Kuparuk River Formation) The primary source of injection fluid is Beaufort Sea water handled through the Seawater Treatment Plant. In addition to this, water that is and will be produced from oil producing wells will be reinjected, and minor amounts of water produced from the Ugnu water source wells will be used for makeup in the produced water injection system. (West Sak Sands) Same as Kuparuk River Formation with the exception of using Ivishak formation waters instead of Ugnu water for make-up water in the produced water system. Estimated Maximum amount to be injected daily - (Kuparuk River Formation) 600,000 BWIPD, when produced water reaches 300,000 BWPD; (West Sak Sands) 200,000 to 800,000 BWIPD. 21 SCANNED ~JUN 1 7( 20Dt.~, I ( Section J Continued '~ Compatibility with formation and confining zones - (Kuparuk River Formation) Water sensitivity tests on core samples showed no significant problems with formation plugging or clay swelling over a range of salinities from 5000 ppm TDS to 100,000 ppm TDS. Water compatibility studies have indicated a tendency of mixtures of Beaufort Sea water and Kuparuk formation water to precipitate barium sulfate or calcium carbonate scale. Therefore, Beaufort Sea water and produced water are handled in separate injection systems. Ugnu water is compatible with produced water, and has been mixed in the Increment I injection facilities since March 1984, with no problems. The Beaufort Sea, Ugnu, and produced waters are compatible with the confining zone. I r ( ( I ( r I ( I I r r I (West Sak Sands) Water sensitivity tests on core samples show the potential for significant problems with: (1) formation plugging due to fines migration, and (2) permeability reduction due to clay swelling in waters with salinities less than 10,000 ppm TDS. Water compatibility studies are planned to ,ascertain if precipitation and scaling will occur when produced and source waters are mixed. If significant scaling tendencies are found to exist, separate injection systems will be developed to keep the waters isolated. In the West Sak Pilot waters are kept separate. The produced waters are injected into the Ugnu formation keeping it isolated from the Ivishak source water which is injected into the West Sak Sands for enhanced recovery. The Beaufort Sea, Ivishak, and produced waters are compatible with the confining zone. ... B. Type of Fluid - gas. Analysis of Composition of fluid - see Figure J-3. Source of fluid - Kuparuk Reservoir. Estimated maximum amount to be injected daily - 350 MMSCF /0. Compatibility with formation and confining zones - full compatibility - reinjection into producing zone. 22 SCANNELl JUN 1 "t' 2004 II ( I ( I I I I I i: ~ ( Section J Continued Subsection 2 Fluid Disposal Type and Source - The injection fluid for disposal is predominantly produced water. The injection stream includes drilling mud, reserve pit water, contaminated crude, diesel gel, glycol, domestic waste water and workover fluids. Estimated maximum amounts to be injected daily - 20,000 BFPD. ... (-- I I r I I [ [ [ 23 SC/\NNE[\ ,JUN 1 7! 20D(~ I Figure J-l. PRODUCTION PROF'\ DIVISION OF SONICS INTERNATIONAL. INC. Petroleum Service Laboratary DALLAS, TEXAS Client fineD fiLf'tCK/\ I NconP-ORr. TED County ()NrHnRf\~~ Lease Depth . T 1\11 I=T Tn ~llpPI v by State ~I 4C\KA Well No. Perl. WA TF'R T ANI{' U:GNU _.I I Field K u par u k Formation. Ugl1u Source of Sample ~nIIRr~ ~()TI=R Date Collected 09-?R-RlJ REPORT OF WATER ANALYSIS Lab. Number Total Dissolved Solids f.:,J-QOE::;9 ?c;?1 Specific Gravity Resistivity (Ohmmeters at 68· F.) 1 _ 00 1 0 pH 4 _ ? Hydrogen Sulfide R.O. ARSFNT DISSOLVED MINERAL ANALYSIS PATTERN I 10 20 n 10 , 0 , 10 15 20 N a fllllllllllllllllllllllll'l "1111I111I11'1 "1'11I1""1 ""I'" 'II" 'II "'1'1'11" -I"" I' "'I" II "'1"1 "" III" I" I '1'1'1 "1111'11'1111'1'1111111"'1""1"" 1''''1''' T "'1""1'11I1""111I'1 CI 10 [ c. 1IIIjIm11l1l11l1l11l11111ll11l1l11ll111ll111l1l11ll111l1l1111l1111111l1l~1I ~IIII~ 11111111111111111111111111 111111111111111111111111I1111111111111111111111111111111111111111 HCO. M g "111""111111"11111111""1""1""1""11111 ~ 1111""1""1""1"" ~ IIIIIIIIIIIIII~ 1 IIIIIII~IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII""III"III"IIIIIIII" ~IIIIIIIIIIIIIIIIIIIIIII SO ,I 1 I Fe 1""1""1"11111"111"1111I111111""1"111"11 LII 1111I11t11l/11I111111111I11'111111II1111I111I1 ~IIIIIIIIIIIIIIIII/IIIIIIIIIIIIIIIIIIIIIIII/IIIIIIIIIIIIII/IIII/IIIIIIIIIIIIIIIIIIIIIIIII111111111 eOI . .. (Number Below Ion Symbol Indicates meq/ Scale UnitJ 1 DISSOLVED SOLIDS ANALYSIS PRECIPITATED AND SUSPENDED SOLIDS ANALYSIS I mgll meq II mgll Total Solids (Calc.) "'~?1 Total Undissolved Solids 1 Sodium (Calc.) R49 ~f,-9 Oil (Solvent Soluble) .3 Iron (Dissolved) 0 n Acid Solubles .4 '( Barium :3 0 Iron _as Oxide: .18 Calcium 1-.3 3.1 Calcium _as Carbonate: .14 Magnesium 9 .7 Magnesium_as Carbonate: .06 r Chloride 1730 34.7 Sulfate _as Bicarbonate ~A6 f, Uni dent i fi ed : .03 Carbonate 0 0 Organic (Ignition Loss) .2 Sulfate 1 () Acid Insolubles .1 [ Sand & Clay Barium Sulfate (Quan.) TOTAL IRON 1 (Qual.) SOLUBILITY CALCULATIONS Calcium Carbonate Stability Index at 77° F .A4 Scaling Tendency POS Calcium Sulfate Stability at 95°F Concentration 0 meqll. Calc. Solubility ?7. 7liieqll, Percent $aturation 0 Barium Sulfate Stability at 95° F Concentration 0 meq /I. Calc. Solubility . Sh, fl. Percent Saturation 0 REMARKS ¿4 8Cf.\NNED ~jUN 1 1200¡n Figure J-2 , PRODUCTION PROFI\_ DIVISION OF SONICS INTERNATIONAL. INC. Petroleum Service Laboratory DALLAS. TEXAS I Client I Field K u par u k Formation Source of Sample ~I=~""'TI=~ Date Collected 09-?~-R1 "neo ^,-",...!<{\ INrnnp.onr.TE.1' County "NrHnR"r.:~ Lease Depth State '" ¡')Sf¡:'J) Well No. Pert. I by REPORT OF WATER ANALYSIS ., - , I I Lab. Number Total Dissolved Solids ~·l-~Ohl) "7R.r:::..7 Specific Gravity Resistivity (Ohmmeters at 68· F.) t;R~J="NT 1.0':'00 pH ·LAR ?c;~ Hydrogen Sulfide DISSOLVED MINERAL ANALYSIS PATTERN c. IIIII""IIIIII""I"III""I"III""IIIIIIIIII~IIIIII"IIIIIIIIIIIIII" "1""11 . .1111111 IIIIIIIIIIIIIIII""I"IIIIIIIIIIIII""I"IIIIIIIIIIIIIIIIIIIIIIIIIII~IIIIIIIIIIIIIIIIII11111 H COa 10 M II IIIIIIIIIIIIIIIIIIIIIIIII"III"III"IIIIIIIIIIII~IIIIII 1111111I11"1111111111111111I1"111111111111111111111111 MIIIIIIIIIIIIIIIIIIIIIIIIII"IIIIIIIIIIIIIIIIIIIII ~IIIIIIIIIIIIIIIIIIIIIII SO. 10 ( 20 U 10 , N . rlllllllllllll"IlI'II, IIIIIIIIII"'¡ 1""1""111I11'11I1""1""1""111I11" 100 ( 10 r 10 o 10 15 20 , r' "1'1"11111111"1'"11 "" 1''''111I'1'1 "1"'1' "'1""1""'''''1''''1 CI 100 10 Fe 1111.111111" 1,1" III"" '11111111. 1111111111111. I ~IIII". II". I. II I . III", .1, III. . 1,11, , 11111 ,,111111 ,,111111111111 I. ",11111111,,111' ,11111111" I" I .1111111111 L. "III "111111,,,.111111 COa (Number Selow Ion Symbol Indicates meq/ Seal. Unit) 10 DISSOLVED SOLIDS ANALYSIS .1 mg!I meq " Total Solids (Calc.) ?7R~7 Sodium (Calc.) RA4Q ,~~4 . :~ Iron (Dissolved) 0 () 1- Barium 0 () Calcium ."2: ~ 4 1A.7 Magnesium ~Rl RO./-. Chloride 1:='400. 4?i4.~ Bicarbonate 1?7 ? Carbonate 0 D Sulfate '?1RQ 4~_~ I TOTAL IRON SOLUBILITY CALCULATIONS o Calcium Carbonate Stability Index at 77° F Calcium Sulfate Stability at 95°F Concentration 1 J.,. 7 meq! I. Barium Sulfate Stability at 95° F Concentration 0 meq ! I. REMARKS PRECIPITATED AND SUSPENDEO SOLIDS ANALYSIS Total Undissolved Solids Oil (Solvent Soluble) Acid Solubles Iron _as Calcium _as Magnesium_as Sulfate as Un i dent i1Teëf": mg!I 2.16 o .46 Oxide: Carbonate: Carbonate: .09 .16 .21 o Organic (Ignition Loss) Acid Insolubles Sand Ie Clay Barium Sulfate .1 1.6 (Quan.) (Qual.) -. ':" t Scaling Tendency NFG Percent Saturation ~o. e":tl Calc. Solubility .III;~. 6fjeq!I. Calc. Solu bility 0 meq I I. SODfUM BY AA: 9550 Percent Saturation o ;¿5 . SCJ.\NNED JUN 1. "J 2.0D4 I Figure J- 3 ARCI) ALASKA ," ':. PRUUHOE BAY CE::Nl kAL( .;.~URATORY ANAL V::; IS r:t:.PUt-<T ************************************** I S~MPL~# G32088 ARCHIV~# G6B~~8:LA I 1 (II:.a t i.:. n , KUt-"ARUK CP!-=#l sampi~ month, day, 11 14 sample d~scription 1 N...IECT ION GAS temp, sample PSIG, ** ** r' ~ q IJ to st.) r B. 'AlEN ,.' line PSIU, met~r# ** ** 18 NUV 1 '::i:::5 ': (. rTI P õ3. n ..... , ~RCU veõ3.r, hour, Sõ3.mple pOlnt d~scrlPtion 19~~ SUCflUN UF C INJ. CUMP. . . . · · · . . . . · · · . . · . · . · ~~;ÃMF·L~· i i M~ · · . · · . . . · . . . . · i OSO·,· · · · · HIJI:'R::; I~MP~k~Uk~ *** LIN~ Pk~~SUK~ 1500 Nil KU'-;t:.N . 3/ #M~rHANI:. e6.~1 IA4KJ:fUI'J JJIUX1LlJ::: .9 &~'I'HANI:. ~.7B PHUPANt:. 3.65 I :::U-~'-'" ANt:. . '+9 N-BU rANI::: .93 ' 1~U-pEN1AN~ .19 N-~I:.NIANI:. .2 C6+ .04 HYLlkUuEN SUL~lU~ *** GkUS~ DRY (lV~AL GAS) 1149 NI:.l (lUI:.AL GAS) 1039.5 GKU~~ ~AIURAIt:.D lut:.AL 1131.6 SP UkAVL1Y (GALC.) .b62 SP UHAVIJY (M~A~.) *** I I f-'kUf-'~Kl Y VALUt:: I ( ( I (:crMMt:.f\J" ::: : . . . . . II . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .'. . . . 1-' ::; 1 C; MUL 'l. MUL Ï'. MUL ï. I1UL ï. MUL i'~ MUL i~ MUL ;~ MUL 1- MUL ï. MUL ~~ B I U/'-:~ f:{ I U I '-:~. f:{ r U / u:.: ...... .... ............ .............. .............. .... ...... II.... ,.( . ......... .... ... ....... ...... .... ..... ... ............ ...... .............. .... ............ .... ........ ........ ........... I ( ~P~ #1 ~AGIL1'Y SUP~Kvl~Uk ti. AI1::.N í.J. '_'I I U:::UN - N::;~;:, K. ~UHI LS AIU-/Y6 DK.AL ~NUW HA-A~U8 ~::, . ~::. 1::. '( ~::; / ~- . L U V 1::. - r\1 ::: ~::. J U M U 1 L~:: :~:; / t.{ U t:: /",11.' f-. 1...1::. Y L?'\!::': I ~·'h~'-',..II:_'_:I ./ t-' 1. LI::. LHUh:i4 I r-lIß"'I-':::UN ;.:-, I U-1:¿U I I I :¿6 t:I-'MI-'Lt:: I t::.U f:{Y...~...".. 1"'/:';\ 'J I...II,-·J', /.'Y· ~I\J í'. ..... ',l . 1;:, '~ ::. ,. 1.' ..............,.... ~·~'«"~^\1\jNEr,· ~\!!N 1I ? 2.0Ü~ ~~O'"'II~~"'" ...¡;...... 0 ,} " ~.- I I I I ·1' I I ( I ,f I f r I I ~. J!'igure J-4 ~. CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. P.O. BOX 4·1276 Anchorage, Alaska 99509 OPERATOR WELL NO. FIELD COUNTY . STATE ARca A1aska9 Inc. WSP-1S Alaska REMARKS & CONCLUSIONS: .. Cations . -Sodium ............. Potii$slum . . . . . . . . . . . Calcium. . . . . . .. . . . . . Magnesium. . . . . . . . . . . Iron ................ mg/1 10740 255 170 28 TELEPHONE (907) 562-2343 ANCHORAGE INDUSTRIAL CENTER 5633 B Street WATER ANALYSIS REPORT DATE Julv 5. 1984 LOCATION FORMATION ~~shak._ INTERVAL SAMPLE FROM Barium (Ba), mg/l-------- 5.6 Strontium (Sr). ma/l-----22 Iron (Fe).ma/1----------- 1.5 lAB NO. 5806-2 meg/1 467 . 18 6.53 8.48 2.30 Anions Sulfate. . . . . . . . . . . . . . Chloride. . . . . . . . . . . . . Carbonate. . . . . . . . . . . Bicarbonate ......... Hydroxide. . . . . . . . . . . mg/1 47 1 6000 o 1970 o megl1 0.98 r 451.'0 o 3' . 31 o 484.49 -- Total Cations. . . . . .. . . 484.49 Total Anions.. .. .. . .. . .. . Total dissolved solids, mg/1. . . . . . . . . . 28210 NaC1 equivalent, mg/1 ..............27767 . Observed pH . . . .'. . . . . . . . . . . . . . . . . . . 7 . 0 1 Sample above described J ! : ¡ ! II ¡: I,. ; ; ¡ j : I,I! II': 1 ~! ,: ¡ " : ,: 1 ¡, - - ;J _ -11' I ' . 1 ¡;;: ¡I; i! II ¡ i: II ';, J I : II J , ! : \ 1 I ! j . I" . -. 1 ,; , 'I ~ ! Na '. it:'; I 1 1'1 1« j'; I .- ,'; : ~ !' I ,I: ¡ , ..1:,:: '.! I :' ,¡ , ' , 'I ' " , ¡ ;. II i I ¡ I ;: ! ¡ . I: ;. .' ',- Ca : :1 i,' !, 1! ! 11' ,: . ::J !: (' ,¡ ; i ì¡ ¡ ¡ , ¡ ¡ I .: '¡ t: : ! I ! I I ! ~ : 1'.: : . ,I ,;. ; :! I ¡ i j ¡ " i I! i .. ,';, : , Mg ,! II ¡'" . ~ I II I.;' .,,1 , ,,; , I II I' :. ¡ ¡I· I I ':¡: "!j ,:: ;¡; í! ! . ; !) ¡i. : : ,~ I; Î I ¡ : Ii 'J ' , : . I Fe I;' í ;" i!' - i; ,¡, !': ~; ,¡,II; ,¡, ' : I ,.' . -1111 , !: I I I ' ; !: I!: , ~ I : . I ,', ¡ ; ~ : i ¡ : Ii' I ~ ' : 1 . I Specific resistance @ 68° F.: Observed .......... Calculated. . .. . . . . . o . 29 ohm.meters o .J6 ohm-meters WATER ANALYSIS PATTERN Scale MEa per Unit :: j ¡ , III ; I C1 i ~ I , , II J, i I ; I ", , . I , , ': i . ';; L::; ., " I I "1" :.: , ,I ¡!: ¡ i;; ':: 100 - , , I ¡ I :: I.: ; ! ;,. .,< I· ,,; . r . t ! I 1 Na 1 : ~. : I :, :,' ':, ::: :,. ,,' '1,': ~ II :, C1 ; 1! !:! 1 " 'i I 11 I I ' ' " "1 ' '.' .. ~ , ~ J I : ~ J I .' 'J , 1 " " 11 'I ~ I 'I I:" i: I::, " : 'I : I , 'I I ' , ; - :,: ~ I ¡; , . I ¡ - < : ¡ ! ¡ : ; I : :: :. ¡ ! : , ~, ! :: '~!. I I , , , II ,.:, I·. 'I I. : :,' I :. ~,: ;: 'II,. it! i ¡I: :: q I : ¡I! . I '" I I, .'. II I , :: '. ¡ î' ; ) i j ¡ ¡ ¡ ! ¡ "I: ;;) J ), í ' . I' .;' If,' II!' Ii':;. :111 , " " i' '1·'1: I,;: ': I ¡;:!, ¡ ; ',. ; i. I,· ,~ I I I' ¡ r I , ì;!, I:. : Ii:; . ¡ :: i:' :! 1 i ;! ¡ '::; ~ j; II I' I " ¡,' " I! I,,· ,.,. , i ~ I: :; '·\1 ¡ ~ ¡ I: :. ¡ ¡ i :. ¡,! : " ,! I ; :', ~ !,: ~ ~ " i! t , ' i' I ¡ ¡ ; ¡ I·, ¡II! " I I! ~ ; i ì I I . ¡ I I J '- ,_: ! - ! ; :: ¡ . I: ¡ j ¡ 'I I ; , 1.1 Ij' . ¡; :! I ' I ,I ¡:t I'· , Iii: , I·' ¡ .',: :: II "! ::, : ,¡ ¡ iI' : I, ¡ I : l HCO' 1Ó Ca SO' 10 Mg CO' 10 Fe '2.7 CO' HCO' : ,,; I:J "; .: I! ,I ,¡ i ¡ , , , ~; I; I i ': j i: I t,; ¡¡I:: . :; !:! I . I ~ I i ¡ i ! : , - I III' :::: ¡:: i SO· CNI ..I". In lbo.. ,,,pl'lS IMI"óes Na. It. IftCI L " NOTE; MV" . Millig'.",' pe' h'" Mtqf1 . MiRig"m ,qul".I,n' pt, lit., Sodium Ctllortdt .qui..lt"' . II, D""I.p , H.w'tI_ aleul.'ion "om CornpGfttfttl SCt:~NNED ,JUN 1. I,? 20D4 I I I I I I ( I I I' I I I " ~, SECTION K Injection Pressure 20 AAC 25.402(c)( 1 0) 20 AAC 25.252(c)(8) The maximum wellhead injection pressure for enhanced recovery injection wells in the Kuparuk River Formation is 2550 psig for water and 4200 psig for gas. This pressure is the maximum discharge pressure of the injection equipment. The average injection pressure in the Kuparuk River Formation injection wells is estimated to be 1800 psig for water and 3900 psig for gas. The maximum wellhead pressure for fluid disposal wells is 1500 psig. The average injection pressure is 700 psig. The maximum expected wellhead injection pressure for enhanced recovery injection wells in the West Sak is 2000 psig for water. The average injection pressure is estimated to be 1100 psig. I I [ [ I 28 SCf\NNED JUN 1 r'i! 20Dl~, I I (, ~~ SECTION L I I I I ( r I ( ( - ( I ( I ( I [ I Fracture Information 20 AAC 25.402(c)(ll) 20 AAC 25.252(c)(9) The proposed maximum injection pressures for the enhanced recovery and fluid disposal wells will not initiate fractures in the confining strata which might enable the injection or formation fluid to enter freshwater strata. Subsection 1 Enhanced Recovery Injection in the Kuparuk River Formation, above formation parting pressure, may be necessary in the future to allow for additional recovery of oil. In no instance would such injection pressures breach the integrity of the confining zone. The Kuparuk Formation is overlain by 2000 feet of confining shales which act as an impermeable confining zone. Any fractures which may occur in the injection zone (Kuparuk River Formation) would be confined to that zone and would not significantly penetrate the confining shales. Increment I water flood performance and pressure transient testing in the CPF-2 area have strongly suggested that preferential flow exists in the north-south direction. Any fractures induced by injecting at or over injection parting pressure are not thought likely to affect this tendency and in fact could reinforce it. This is expected to have a positive effect on water flood efficiency based on the line drive configuration of the water injectors along the same axis as this directional preferential flow trend. The Kuparuk River Formation is separated from producing horizons and water bearing zones by over 2000 feet of confining shales. These shales provide a substantially greater barrier than necessary to contain fractures within the Kuparuk Formation. 29 cr'" t ~~B ~,~ðE'ïr \ ~ I¡ n {\,n 1 ~~I 2 0 0£1 t.:'1\V6;\nH~ ,U d! ~n\1 .t d _. ! 1· I I I I I r r ~ ~ ~' Section L Continued Injection in the West Sak Formation, above initial parting pressure, may be necessary to allow for additional and timely recovery of oil. In no instance would such injection pressures breach the integrity of the confining zone. The West Sak Formation is overlain by 120 feet of confining shales which act as an impermeable confining zone. I I I I The West Sak Pilot Project water flood performance has indicated that the fracturing pressure is a function of both reservoir pressure and, to a lesser extent, reservoir temperature. As the reservoir pressure and temperature increase, as a result of water injection, the pressure at which the reservoir will fracture also increases. Injection above parting pressure is expected to be necessary in the West Sak formation to facilitate hydrocarbon recovery. Injection pressure will be limited to a value which will assure compliance with the requirement of 20 AAC 25.402(b) to prevent movement of fluid into freshwater. Subsection 2 Fluid Disposal ,....- -, I r Injection pressures in the fluid disposal wells will norrnally be maintained below parting pressures. Injection at higher pressures, however, will not result in formation or injection fluid movement into freshwater strata. I I I I I I The confining shales below the injection zone are in excess of 2000 feet vertical thickness. The upper confining zones consist of numerous interbedded confining shales and mudstones averaging 10 to 50 feet thick which are overlain by over 1300 feet of permafrost. 30 SCl\NNEL' ~JUN 1 ¡'(f 200~~ I I I I I I I I I [ i' 'I. ~.. SECTION M Formation Fluid 20 AAC 25.402(c)(l2) 20 AAC 25.252(c)(l0) A water analysis for the Kuparuk River formation is included as Figure M-1. A water analysis for the Ugnu aquifer is included as Figure J-1. A water analysis for the Ivishak is included as Figure J-4. I [ I I I I I I 31 SC¡.\NW\'E[) ~,~UN .~ 7 200/1 Figure M-l PRODUCTION PROFITS DIVISION OF SONICS INTlRNATIONAL. INC. Petroleum Service Laboratory DAL.LAS. TEXAS I f I I Client Anco ALnCl<:O I NCOnr.onnT¡:n County lease Depth WJ:l I f"r-l I m\,l='~ by f Flel" k'IIPORIIk' Formation Source of Sampl. J7~-~ Date Collected 0 I ¡ / {)Nf"'~'1RAGr _State ,,,I {)C:Is~" _Well No._ Pert. SAf'\In REPORT OF WATER ANALYSIS I Lab. Number Tota' Dissolved Solids r.:,J-40~'=' ?1c;1C¡; Specific Gravity Resistivity (Ohmmeters at 68· F.) 7 1=1 ,....I=i~:'I\IT t 01 77 pH LAB . ?R Hydrogen Sulfide f DISSOLVED MINERAL ANALYSIS PATTERN , 10 20 l' 10 , N. rllll....IIIIII....I.."tttll....I'IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII111III 100 o l' 20 ( C. IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII~IIIIIIIIIIIIIIII "1"11 ~ 11I1""1""1"" 1-111I1" "1"" 1""1"1111 111"11111I11"111"" 1""1"111""1"" ~IIII"" 111111111111111 H COI 10 M I 111I1111I1""1""1" "1"11111"1111111111111I1 ~ 11I11111111111111111111 ~IIIIIIIIIIIIIIIIIIIIII 11111" "1""1" "1"111""1"111 ""I ""1"111111I111I11""1"" ~ 11I1"111"111""111" SO 4 10 10 f to III r 11111 ttt I ttt 11111111111'''111''11111I11"''111I1 ....111I1111..1....1..111 CI 100 r 10 . Fe I"" I" 11111"1""1",,1,,,,1,, 111""1,,,,1111I ~IIII"" 1""1",, I" II L 11.111" 11111 11I"11II...I.."I"..IIIIII.."I"..I.."I.."lttt,I"..I""I,,,,1 ""I.. "III" Lilli ""1..,,1""111I1 COI {Number Se/ow 'on Symbo' 'ndicates meq/ Sea'e Unit' . 10 .( DlssnLVED SOLIDS ANALYSIS mgll ?4~4~ RRQO o 4A 1t)9 - 7 1 1 ROO ~AQO o ~ meq " I Total Solids (Calc.) Sodium (Calc.) Iron (Dissolved) Barium Calcium Magnesium Chloride Bicarbonate Carbonate Sulfate ~R.t._7 o _7 !=å-4 -I-. ::\:-,!:?_R AO_~ o f I TOTAL IRON SOLUBILITY CALCULATIONS ?~ I Calcium Carbonate Stability Index at 77° F Calcium Sulfate Stability at 95°F Concentration _ 1 meq II. Barium Sulfate Stability at 95° F Concentration . 1 meq I I. REMARK~ PREC'1PITATEn AND SUSPENDEn snLlDS ANALYSIS' mgll 55.54 4.65 8.71 Total Undissolved Solids 011 (Solvent Soluble) Acid So/ubles Iron _asOX ide: Calcium _asCarbonate: Magnesium_asCarbonate: Sulfate _as Unidentified: 3.46 .29 1.22 3.74 - 1 Organic (Ignition loss) Acid Insolubles Sand,. Clay Barium Sulfate 5.45 36.73 (Quan.) (Qual.) -b.-73 Scaling Tendency NFG Calc. Solubility r;=;!,. Rã}eq/I. Calc. SolubilitY . fMq/.. SODIUM BY AA: 9580 Percent Saturation . t 7 Percent Saturation lno 32 8C!-\N~~ED ~nJN 1 ? 2004 I I I I I I I I [ I ( I I I I I I I , SECTION N Aquifer Exemption 20 AAC 25.402(c)(l3) 20 AAC 25.252(c)(ll) All aquifers or portions of aquifers lying below and within 1/4 mile of the KRU are exempted aquifers for Class II injection. (ref. 40 CFR 147.102(b)(3) and 20 AAC 25.440(c).) 33 SC'~tN~~ED JUN 1 {f 200,~ I { I I I I I [ ( I I I- I [ I I I I [ SECTION 0 Hydrocarbon Recovery 20 AAC 25.402(c)(l4) Total expected hydrocarbon recovery from the Kuparuk River Field is 1.6 billion barrels of oil, or 30% of currently estimated oil originally in place. Of this amount, over 1 billion barrels is attributable to waterflood. Potential hydrocarbon recovery from the West Sak is estimated at 2-4 billion barrels of oil or approximately 20% of currently estimated developable oil originally in place. All is attributable to water flood. 34 Sf'" ·t\ IÌ\~~\~E-'r~) D~ UN· 11. "7 20 Oll. I;,,) ~" "~II~ 11 \j 1-.,~.ß Ik) . J d .. ., r I I I I I I I I I f ( SECTION P Mechanical Integrity 20 AAC 25.402(d) and (e) 20 AAC 25.252(d) and (e) In newly drilled wells, the casing is pressure tested in accordance with 20 AAC 25.030(g) (see also Figure 1-1). If converted to injection, the casing is again pressure tested in accordance with 20 AAC 25.412(c). The casing annulus pressure is then monitored on a daily basis and recorded by the drill site operator. r ,. I I I I I I [ 35 5CANNED ~njN 1 fiJ 200,'~ I I I I I I I I ( ( I ( ( [ ( [ I I I ~ " SECTION Q Wells Within Area 20 AAC 25.402(h) 20 AAC 25.252(h) The wells within the area of review (i.e., KRU) are shown on the plat (Figure B-1). To the best of ARCO Alaska, Inc.'s knowledge, the wells within the area were constructed, and where applicable, abandoned to prevent the movement of fluids into freshwater sources. 36 . .! "') ?nO~ ~.'...~.'" ¡\\\r..~I.\.~C¡,!) ~UN I, 0 I.:/-,r l",;,1~~J'&-' '~\\8':~~ ~\:I K~.... ',..~' ~,," ." . ARCO AlaSka. Post Of Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~~ ~~ SECTION R March 27, 1986 Mr. Chat Chatterton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Kuparuk River Unit, Variance Request Dear Mr. Cha tterton: ARCO Alaska, Inc. requests two variances from certain reporting requirements, as allowed by 20 AAC 25. 450(a), for injection wells within the boundary of the Kuparuk River Unit. Under 20 AAC 25.450(a) variances may be given at the Commission's discretion if: 1) injection is not into, through or above a freshwater aquifer, and 2) injection does not result in an increased risk of movement of fluids into a freshwater aquifer. The aquifers underlying and extending one quarter mile beyond the Kuparuk River Unit boundary are exempt from the definition of freshwater. Injection within the boundary of the Kuparuk River Unit is not into, through or above freshwater. The requested variance is for reporting and so does not increase the risk of movement of fluid into freshwater. f' [ A variance is requested from the monthly reporting requirement of 20 AAC 25.402(d) & 20 AAC 25.252(d). The injection wells are not equipped to monitor the casing pressure automatically. The casing pressure was not included in the design of the automation system because it was not required information by either the Commission or the Environmental Protection Agency. This information is not currently required by either the Commission or the Environmental Protection Agency. These pressures are checked and recorded daily on every injection well by the Drill Site operator. This data is maintained in a paper data base by ARCO. The purpose of the daily check of casing pressure is to verify no commurÜcation exists between the tubing and the casing. Prior to initiating injection the wells are pressure tested to ensure isolation of the tubing and casing. To submit the casing pressure monthly would require either extensive reworking of the automation system or expensive manual compilation. The expense associated with monthly submittal of this additional information does not appear warranted. A variance is requested from the 200 psi change in casing pressure reporting requirement of 20 AAC 25.402(e) & 20 AAC 25.252(e). This section requires immediate notice to the Commission and corrective action if the casing pressure subjects the casing to a hoop stress that exceeds .70% of the minimum yield strength of the casing, or if there is more than a 200 psi change in the pressure between consecutive readings. ARCO requests a variance to use only the 70% limit as the trigger for immediate notice and 37 f,,""'-\. ¡ 1.'.1. ~ '\~ ~..., r· II tl HìI ~ i ~'~i 20 0 ~ ~.)Cú'\~\,h~::r) (.n.n\! Ji. ( _ ./J' ~\ ...~\ I.: ,) ~,d $I<~) I r~ C ') d 'j.J ~., ¡ l.~ I ,,J," 1 ", .\': ì j"!' '~~ ,I: r,·,.. !: 1(' Mr. Chat Chatterton March 27, 1986 Page 2 corrective action. By using the 70% yield pressure limit, the injection wells can be monitored to detect leaks and operated safely. In contrast, due to changes in injection pressures and fluid temperature, the 200 psi change is not a viable mechanical integrity test for injection wells in the Kuparuk River Unit. A review of casing pressures in Kuparuk water and gas injectors for the period of March 1 through March 23, 1986, was conducted to evaluate the impact of the 200 psi reporting requirement. The review indicates that it would have been necessary to contact the Commission over 190 times to report casing pressures which changed over 200 psi from the previous day. For February 1986, a check of gas injection drill sites showed that on Drill Site 2A alone, it would have been necessary to contact the Commission 84 times to report a 200 psi change in casing pressure. The casing pressure changes in excess of 200 psi are attributable to thermal affects and are not indicative of a loss of mechanical integrity. Casing pressure data to support this is available for your review. To provide immediate notice to the Commission of each 200 psi casing pressure change would require extensive manpower. Your favorable and timely consideration of these variances is requested. Sincerely, QD~ f.f. D. Weeks Kuparuk Operations Manager J AA:pln 38 . ~·I\~'·'\iE~·r n H\~ i F'i 200A 5{';, ' r: '\J ~ '~1I,~" [I..' .,J lì) 111 J.. ~.... '" . ~, ( , . l ~. j-L f U K,te. ¡;-{ I: XJ I I 11 I T ::~ I< UP(IF:UK r~ I VEF.: FIELD' I..J {1 T E f;: FLU 0 D P E F~ (-1 J:. r· A F~ E A DE:SC¡:\~ IPT ION BY ,SECT IO~ ~~ : . T \ ø \l, F:: t! [ 1 U ^ M ,. T11N, R8E, lIAr"l^ 'I ~"~.' :;), ,(~, íO, 1~, 12, ) "/ ~:;, Ó.. -l, D, ':;.).. '13, 1A, '1~), i6, 1, 2, ~~ , 1 (-) , 1 i, 1 2 , 1 ::) , 15, '\b, 21, 22, 23, 24, 26, 27, '2B, 29, 32, 33, 35, 36. '14, I') 1:-· ,~. ,) , ~~ -4, T 1 I;) N, I~: ',> E , U ^ ¡'''I ^ T11N, R9E, lI^f'1A 'í I 2, :5 , -4 , ~5 I 6, "(' I a , '1,' íÜ, 1'1,17, í:J A!.!. T i (-) ¡\¡, f;:'1 (-) E, U ^ 1"1 ^ T11N, rnOE, LIAN^ r IS AI. I. T11N, rn1E, lLN... 5 1 I.> , -1 1 8 , i"(', 1 H 1 1 </ I 2 (-) , 30 r 'j ,,:,: ;\1, ¡:;: dE, 1..1 t. n" 'T 1 ~) N, H BE, U .\ (1" 'j, ~"~' 11, t~:,~, 13, 14, 2~:·~.1 :} if / ~~~ ::> 1 26 , ~;:) ~5 , :3 b 1 2 , 1 3, 2 3 , 2 4, 2 ~5, 2 Ó, 3 4 , ~~5, 36 ·r j ,;:~ ¡··,I, r;~ ') E, U t. ""I A' T f ~) N, I~ <ï E, U ^ r'¡ " ~11. I. 3, 4, 5, 6, 7, 8, 9, 10, 15, 1 6, 1 7, 1 8, 1 9, 20, 21-, 22, 25, 26, 27, 28, 29, 30, 31, 32, 33, 34, 351 36 I' T 1 ::,! N" F: i (.) E, U t, i'''¡ t, '.::, Ó, '(', B " 19, ~~0 .?'/" ::~U, 34, :.;):-~, ~Sb .¡ U, 9, 1 ~~ , 1 Ó , 2'1, 22, 23, 2 9 1 2> 0, ;:'; í , 11, ? :~> , ::'.: Ó , ,o"!,,,¡ ,~) ,\'~ .33 r '; 2 N J f;: 1 i E~" U ,'. i'í " :~) í . pj ~ - ~ JUN 1 ? 20011· (' ( Section B Plat 20 AAC 25.402(c)(l) 20 AAC 25.252(c)(l) Figure B-1 is a plat showing the location of all wells that penetrate the uppermost confining zone within the Kuparuk River Unit boundary, i.e., the area covered by this area permit application. >' B-1 SCANi"ED JUN 1 LllDD~· ,JUN 1. 7 lODe\, >- C-l 20 AAC 25.402(c)(2) 20 AAC 25.252(c)(2) Operators/Surface Owners SECTION C ( ( SECTION D Affidavit 20 AAC 25.4-02(c)(3) 20 AAC 25.252(c)(3) D-1 II ~ !Ioo JUN 1 If 2004 ) ) SECTION E Description of Operation 20 AAC 25.402(c)(4) CUl'f'lf I 2/ f"?();;~' -tWð Injection operations at the Kuparuk River Unit are divided into tJ:w:.ee broad categories: " -e 11 ¡, f}1f(' ~ tI "'of" (' eN)"1' f ' Subsection 1 (page E-l) w:ltcrflood, . / , dl$þ/),s411 ð f -I'I",~.;¡. ¿t-IJ.~tl h fIw S"''''~Cft IHeI {"Drn "h1IHJI.R Subsection 2 (page E-12) ¡voducerl \V~wr tiiiPQsal, :lAd ~."fl._ l'1ðH-- NJ""-'.I1IIS.:f/IIIØI J"sf~ S~~tion 3(?aJ~ F 12) Ùh..",,~"\..¡..... :llj....\." ~Nn. ..f ILI''/.$ tC"..".,. Ul4,f apøtll'llWI s. Subsection 1 ~v a t(.r flood F If'h NIf""'¡ ~r()ltJfJ" t... EIt/'(lh('" , r Watcrflood recovery injection wells are used for the introduction of additional fluids into "lill.Uf'¡'~ t''''''.''(''~ the oil reservoir to increase the... recovery of oil. Three types of 6OcorvJ~r-y recovery injection wells are currently used: water injection, gas injection, and water-alternating- gas injection. (See the Kuparuk River Field, Full Field Water flood Project Testimony, May 23, 1984, for details.) Additional methods of enhanced oil recovery may be used in the future. Future injection wells will continue to be designed, constructed operated (and monitored) to ensure the injection fluid is entering the oil reservoir. iIo' Subsection 2 f\oduc.edWu.tcr Dlsµu~éLl Wells ;¡'/,,/I L/¡$1'6'St::'/ Produced water disposal wells are used for the disposal of produced water and other fluids generated during Unit operations. The produced water is water which is produced with the oil and separated from the oil and gas at the central production facilities. The remaining injection fluids are non-hazardous fluids generated by Unit operations. Injection is into the lower Ugnu sands. Central Production Facility 1 and 2 have produced water disposal wells and a third is planned for CPF-3. E-I <,/.,)\\li\jED JUN 1 ~t 200~· ) ) ~ ..Annulus Inj~ction " wastes generated by rilling operation are injected t) low the surface casing hoe of tandard Kuparuk Field ell. After the injection oper tion is complete, each a nulus is seale with cement displace to the bottom of the perma ost with Arctic-Pack hich the Ugnu or We Sak formations are cored not used for ann ar injection. owever, these annuli are as standard wis. >- E-7 .I, :\J \\1 iC í' 'I n r¡\,1 ""L ¡:-¡ ?OfH "d \~~, .J ~tl.\..,.) r-..J y j ~ .' ~11 110. ~..;,",r ) SECTION F Pool Information 20 AAC 25.402(c)(5) ~fA, "., ~fiI' eÞt¡'IJII~#'¿ ,.'C~ -fì,.(j~ 4ft/l.. The ~ affected by th.v wo+¿r injection pfl j 1 ~ J.å the Kuparuk River Oil Pool, defined by It .$lrJ/~ ø~ ... Rule 2 of Conservation Order No. 173 as the a'Al 'mu13tion ofoH that å common to and correlates with the accumulation found in the Atlantic Richfield Company West Sak River State No. 1 Well between the depths of 6,474 and 6,880 feet, MD, or 6387.9 and 6793.9 fit # s , s',..erl... feet, subsea. The top of thii "'co'rnulatioI1 range\ from 5700 to 6500 feet, subsea, in the Waterflood Permit Area. >' F-1 i\~ h~ i;= ~' _ ~¡I ui:\J ~ '7 ?Or.:'l c, - J /:"".l_, ,-§ ~Jd d _,.. t, t_ .1..'1J ) ') SECTION G Geologic Information 20 AAC 25.402(c)(6) 20 AAC 25.252(c)(4) Geologic information and figures on the zones used for injection in the Kuparuk River Unit are included in three subsections: Subsection I (page G-2), the shallow sands aquifers, Subsection 2 (page G-9), the Ivishak formation and, Subsection 3 (page G-13), the Kuparuk River formation. >' Subsection 1 Kuparuk River Unit - Ugnu and West Sak Sands I. Injection Intervals A. Stratigraphy and Lithology Strata which ARCO Alaska, Inc., (ARCO) refers to as the Shallow Sands in the Kuparuk River Unit (KRU) comprise a portion of the late Cretaceous and early Tertiary deltaic depositional system in the KRU area of the Alaskan North Slope. This includes all the interval between T-3 and the K-12 markers as shown on the Generalized Stratigraphic section (Figure 1). Significant amounts of heavy oil occur in two zones which ARCO refers to as the West Sak sands and the Ugnu sands. These zones are oil-bearing in the KRU between 2000 and 4500 feet subsea. Although there are other horizons which locally contain heavy oil, the West Sak and Ugnu are the most laterally extensive. Pilot and experimental enhanced oil recovery (EOR) processes involving, but not limited to water, gas, steam and/or chemical injection into these zones is planned to evaluate their commercial potential. In addition, the KRU is injecting waste water (such as produced waters from the Kuparuk River Unit), into the lower Ugnu in a disposal well at the Central Production Facility No. I (CPF-1) in the southern Kuparuk River Unit, updip from G-l SlJ:ìNNED JJUN :1 if 2DO~, ) ) the oil accumulation. Similar injection activities are planned for CPF-2 and CPF-3 facilities in the near future. West Sak is an informal name applied to a sequence of oil-bearing sands between 3744 and 4040 feet measured depth in the ARCO West Sak River State No.1, Sec. 2, Tll N, RlOE, UM. The West Sak sands most likely are equivalent to the Schrader Bluff Formation of the Coleville Group, and are Late Cretaceous in age. The West Sak consists of fine-to very fine-grained silty sand with interbedded silt and clay, and has an average thickness of 300 feet in the KRU. Core data shows that porosity ranges from 25 to 35 percent and permeability ranges from 10 to 600 millidarcies. The Top West Sak Sand Structure Map (Fig 2) shows that this interval occurs between about 1000 and 4500 feet subsea in the KRU, and dips gently to the east/northeast. The Ugnu sands derive their name from an oil-bearing interval in the B.P. East Ugnu No. 1, Section 17, T12N, RI0E, UM, between 2716 and 3260 feet measured depth. The Ugnu sands are divided into a lower and upper member by a shale bed at 3005 feet in that well. The Ugnu sands are correlative with the Prince Creek Formation of the uppermest Colville Group and the basal Sagavanirktok Formation, and are Late Cretaceous to Early Tertiary in age. The Lower Ugnu sand consists of fine-to-coarse-grained sand interbedded with siltstone, shale and minor amounts of coal. The thickness averages 240 feet in the KRU. Core data indicates porosities between 25 and 40 percent and permeabilities from 200 to 3000 millidarcies. The Top Lower Ugnu Sand Structure Map depicts the depth of the sand between about 1000 and 4000 feet subsea in the KRU (Fig 3). The Upper Ugnu sand consists of interbedded very fine to coarse-grained sand, siltstone, shale and coal. This unit has an average thickness of 300 feet in the KRU. Core analyses indicate sand porosities between 25 to 40 percent and permeabilities between 200 and 3000 millidarcies. The Top Upper Ugnu Sand Structure Map indicates the subsea depth of these sands occur between about 500 and 3700 feet subsea in the KRU (Fig 4). Occasionally, thin bedded lenticular silty sandstones are encountered in the 200../- foot interval immediately below the West Sak Sands within the Colville Group (Figure 1). These sands range from a few inches in thickness to about 20 feet, and average about 10 feet thick. Porosities and permeabilities in these sands are similar to, or slightly worse than, G-l ~.. ,', i , 'I 1'''-[·' '.. t~ H\~ .¡¡ r"7 200 '1 ~t;b-ìN~\:Jt;.lj Ji ~h\ 'J .iL (; ~!',.~. ) ) the West Sak Sands. B. Formation Water Salinities Water samples are not available from the West Sak and Lower Ugnu sands in the KRU. However, apparent formation water salinities calculated from wireline resistivity and porosity logs indicate parts of the West Sak contains water with salinity less than 10,000 ppm NaCl equivalent (Attachment DIE - 2). ARCa is currently extracting water form the upper Ugnu at 1-6 pad in the CPF-l area of the KRU for use in a water flood of the deeper Kuparuk Formation. Laboratory analyses of this water indicate the water contains less than 10,000 ppm TDS. II. Confining Intervals The West Sak and Ugnu Sands are confined by bounding layers of impermeable shale and mudstone. ~ Beneath the West Sak interval and above the Lower Cretaceous Unconformity in the KRU are between 2000 and 3500 feet of Cretaceous shale. The shale interval above the West Sak sands averages about 120 feet in thickness, is continuous across the KRU, and forms an impermeable seal. The Ugnu interval contains laterally discontinuous sandstone units interbedded with thick shales. These sandstones are stacked sequences that may locally be in vertical communication. However, above the Ugnu and below the T-3 sands there are several thick shales which are capable of providing adequate seals (Fig 1). In addition, both the West Sak and Ugnu sands intersect the base of permafrost between 1300 and 1500 feet subsea in the western KRU. This isolates these formations from communication with surface waters. G-l ç~.(-I·,~\'\~¡E;;C·~; P'~hl\·~ lJ 2004 \."'í!~di"··Ü \:. \I u U&\I ..... v . --=-"~~~I:;~\:~' .- ~: N...· > a: c - t- œ W I- --- U'J. --- :) At o ~ W a (.) C I- W a: (.) 1&1 -' -' - ~ o u ) . li~ua. 1 GENlRALlZID SThA~IGRAPHIC IICTIOff ~ r u,.. ..... _.'f ...c..".... ~...:.... 1Ä.1 . ,'~... :. It, ~ ~~~~ ~4~ø:.:..· ,~; - ..... "1" ~ . t_..;.......;..' ; ~'. ~:.' ." ~~ii!";:"i~·~ J". .t~..::.~:..~::;~ ,.. .... . ,.: . ! -. .. " . ~ ~ ¡~~:~~ - ........ = :~.~.~~~::~ S . 'AU ~:~:r- PERMAFROST: Interbedded gravels, sands and shales. œ "'AUr·.;,~···..,.. O 'IO.T:'.: ::~:./:. . . .. " .... ~~".'~.:,' '-J :.'\.~tH.M.; T-3: ~:~~e~a~~::e~~~ ~:~~~a~~da~~a~~~e:~:~nS~~~~d1~ter- ~¡: ..,.,::.... occurences of coa 1. ~~~~~~:¿~S ~~?T~',:~ K-lt ~~-_-~ K-15: First coal marker underlain with sands, silt¡ and .~..~-.-:,"' shales. Localized coals occur within this Þinterva1. '.~ ':~ '>~',~ ~.k·:~~~i' ~~~:~.~.:; ~ ..,~ ~)~~);i .' .. ~:~~~~~: u".. ;(~~~~ UPPER UGNU: Interbedded coarse to fine sands and shales UGNU ::-;--=-;~-: wi th 1 oca 1 i zed occu rences of co a 1 . .' ,..,..... ;",,". ~:~lr}~~>~ Low..1~·,:·:.:~;;.:.>:) LOWER UGNU: Interbedded coarse to fine sands and shales. UGNU :~:=:::~:~ ;¿ .!.:..:~::.: ----- · ~~.:~.;,..-:::.,~':~ WEST SAK SANDS: Interbedded f; ne-sandstones, s i 1 tstones, WI.' ,:\·:~·x:...··..:=:: and clays. SAIC :=:::=:=:=: SANDS ~~~~~¥~~}~ ----- ~~:)~~~~2: ------ ----- ::'~'~:-. ·::-:·~··1 ----- ----..... .:'..:::. 'f1:~ -or::· ~ o Þ- ~ S5 ~ > C CJ c en ~----~ K 12 ~-:-:-:-:-: ..----- ------ ----- ------.. -...--- ~m~f ..: -: -: -:-::; ------ ----- -----. ------ ------ ------ ------ .----.. ----- .~---- -----.. -:.--~----~ K-12: Interlaminated siìty mudstones and shales with minor silty sandstones. G-.6 Based on data from: ARCa West Sak River State 11 ~Cl\NNEL: ~HJN 1 ? 2.0n~l ~,rè'~," .:;.-::><. y y ARca ALASKA, INC. · .,..., 02 » .C" I\J f" Po ~-,=" ~,. 'i\ '.'.-' "li'U' j r n ¡¡- ,...j'."¡- !J ~""'1' ~. {_. ó - - -' ¡ TOP WEST SAK SAND STRUCTURE MAP 1·-~2000· CI-500' .ZI'¡ .~.? ", -.,''''-:10'''-- # l¡-ì ______ ~ .._,--.---- f-r , ------ I I · I ' , __: I UN I T L______ ---~--.._----------------- ï- r-J , ,__I I . . I I _:~ '________, : KurløUK ø\-yË-ø--üìïi;----:-------- I ! ¡ i I L_, I I ! I J ,.________ ~A;-:;;~;;~;;-I ,~ ~Øl~ /-.0.... ------, , L,-~ · rj-~- ! ;- ~ . G) , . IAI I . tAl (sfl , . . \- - ~ " "- "'~søo '.... 0°0 ~ ,,~ -0 , . - >~'-".'''"G <f'"'''í!~' " \ \ \ Figure 2 y '( TOP LOWER UGNU SAND STRUCTURE MAP '--)2100' CI-500' aZ/lJ ARea ALASKA, INC. , t-----l ~i .. . U. I AI. "4~,. \. ) " 'L, --I . . \ . ._~ . j \ ~_.. \ ....-----. r--- , I I ' I L____ : : ------ , ¡- f I L-.J klU EXPANSION í .-_. I I I I i I , I I I "-,-VË-"-ÛÑ-,-T·---.-------~\: .¡--I \ I KUP'ftUK r'-"" l\---. \ I I I I ' L_____ __..__-__-_____________----J , l_____________l · ~-l ~. ~ --r=L--_---- -- f-... -------... ._ J \ W\ . . . . . \ . \ ~ G) ."-" , A.. _. ._....:."'~. " ...,. "00 \~ \ - t:/' ' ~ \ \ \ , . tOOl ¿ 1 Nnf G3NNW~~i9ure ) y y ARca ALASKA, INC. TOP UPPER UGNU SAND STRUCTURE MAP .e-IZOIO· CI-500' 12/11 ... \ \ \ \ I I __________J ----------------- .\ HUll r-------- ì I ' , I ' , , I ' · "---ì , . , , L 'I -------------. I KRU EXP.HSIOH : , LJ.... ------- L-.- \_. 1 l I I \ __-:_____.J ,"'- \ 1.'\ L.., \---------~ .. L .'~-' . IAI I ~ . . , au "',' . . ... 1., --I \ , . , . I . . ... II . .',,1A1 . ... \ \ \ 'Vaal l T Nnf' J[i¡\j~r,~..:·, .-. I I I I I I I ,__I I G) r-I--' , ,__I . _0> i I , . I L_____________ KUP.IUK RIVEI UNIT \ ) ) Subsection 2 Kuparuk River Unit - Ivishak Introduction A major stratigraphic interval in the Kuparuk River Field area that may be utilized for future class II fluid injection is the Ivishak Formation of the Sadlerochit Group. This is the main reservoir in the Prudhoe Bay Field. To date, limited penetrations into this stratigraphic interval in the Kuparuk River Field have not discovered commercial hydrocarbon accumulations, and it is currently believed that trapping mechanisms are either nonexistent, insignificantly small, or undefinable by today's technology or the presently available data. A. Str a tigr aphy The Sadlerochit Group, late Permian to early Triassic age, is divided into three distinct geologic formations: the basal Echooka Formation, the Kavik Shale and the ~ overlying Ivishak Formation· (sandstone). The Sadlerochit Group overlies the Per mian Lisburne Group and is overlain by, in ascending order, the Triassic Shublik, Sag River, and the Jurassic Kingak Shale Formations (Fig 1). Within the KRU the Ivishak varies in thickness from less than 550 to over 650 feet and the structural top varies from less than 8,000 to over 9,000 feet subsea (Figs 2 and 3). Lithologically, the Ivishak sandstone in the KRU, is generally believed to be of a lower energy, distal deposit of the deltaic system than its equivalent intervals in the Prudhoe Bay area. The porosities are comparable to those of Prudhoe Bay with much lower permeabilities. Zone 4, the uppermost zone within the Ivishak Formation, is interpreted as distal fan delta, flood plain and channel fill deposits. It consists of uniform fine-grained sandstone, occasional silty sandstone and minor mudstone beds. The interval thickness ranges from 180-230 feet; porosities of 18- 24% are comparable to those of the same zone in the Prudhoe Bay Field. A major difference is found in the permeabilities. There have been a few deep wells penetrating the Sadlerochit Formation in the Kuparuk Field and based on limited well data the permeability in the area ranges from 1 md to +/- 100 md. Zone 3, is comprised of distal to mid-fan delta and channel fill deposits. It consists of fine-medium grained sandstone/pebbly sandstone and conglomerate. The interval thickness ranges from 80-120 feet. Averag~l'~rosity is 17-20%. SCJ:~\~~~\]E[:: <JUN 1 j' 20D,1· ) ) Zone 2 consists of channel fill, flood plain and distal-fan deposits. It is primarily a massive fine-grained sandstone up to 250 feet thick alternating with minor claystone/mudstone beds and pebbly sandstone. This interval has porosities up to 25% and permeabilities ranging from a few to 800 md. Zone 1 consists of distal deltaic, prodelta deposits representing the transition of underlying marine environment of the Kavik Shale to the delta front environment of the lowermost Ivishak Formation. This lower unit ranges from 80-120 feet in thickness. It is a very fine-grained sandstone interbedded with siltstone and mudstone. The porosity ranges from 16-20% with permeabilities of less than 30 md to 50 md. Structure The Sadlerochit Group of_ the Prudhoe Bay Field is a part of a northwest-southeast trending anticlinal complex. In the Kuparuk Field, the structural dip is to the south and in general the faulting system is not as extensive and complex as in the Prudhoe Bay Field. Normal north-south and northwest-southeast trending faults occur with throws ranging from 50 feet up to 200 feet. The structure is defined by change in facies in the north, regional dip in the south, the Colville high in the west, and northwest, and northwest- southeast faults in the east. A few small Sadlerochit closures of no significant size have been identified by seismic in the Kuparuk Field. These closures are controlled by regional dip and structural displacement. Formation Water Salinities and Hydrostatic Pressures Tests from a location south of the Kuparuk Field indicates average salinity of 19,000 ppm and hydrostatic pressure of 4300 PSI for the Ivishak Formation. References Jones, H.P. and Speers, R. G. (1976) Permo-Triassic Reservoirs of Prudhoe Bay Field, North Slope, Alaska, in North American Oil and Gas Fields, AAPG Memoir 24, p. 23-50. H. C. Jamison et at, 1980, Prudhoe Bay A 10 year Perspective, in Giant Oil and Gas Fields of the Decade 1968-1978, AAPG Memoir 30, p. 285-314. G-1 ... -" I. ~ ~ '\r"~ --. q' ~:¡ ';1 r',' 'Ì n n,~ i;.'þçl\~~.~;\t:.L) <:,.,hJh .t :1 L",U',' ) ) "' ,r:/êC~~J~:._ J b_ " ;I..J'-JL,· r.· 1"\1"\ ...., ,..., lCAT'- "'- . - ._~-t-...\ .~"' . ~.' ,. ..J U -. .,~tt ---¡¡p--.'- A.".Co.-EXXON "'UDHOI "A Y St. No. 1 IL .... . w..' I~¿. .... ~. ..GaIL A.".Co. W. IWIt It. W. IAI ... .... 1 No. ,·n·n . . 2-''': IAQAVANlMTOIC ,. '2000 .001I- -...~ . -- ". ......,.-- COLV1UI ca.. '4000 ... ..' . ...- --- ,1000 , . -, . . lOW,.. C..., "" ... - ==::, ~:.. . .,~OITOHI. 1000 Ii . . _..._.... ·..··1 ... _ . . , ...~.C.~.._ í,j . LI........ G', .10.000 1000",.- ' - ~............ -, KINGAK IHA. lOGO . ~ .-~ ~... 'cn:rG, IADLI~~- -. ~ , 10.ooo.(--···~ . .". -"- -.-- _ .'---1- f- ......ou'*,... -----.. ... --,t: -.. .-...-...... INOICon GP. , - - -. '. . " 12.000 , 20000 . o 1. "'¡In -- o 10 "'" Fig. 1 - East to west cross section, Prudhoe Bay - Kuparuk River Fields comples. For location, see structure mpa of Ivishak (Fig. 3). H. C. Jamison et ale p >' o I o 5 I , 10 Miles 16 Kilometers 8 T 13 N ~.... . " :fIIIg - Á ""0- ----, ~_._¡ o I o , , I , , ~ ( \ ,~ "'---- , T ,~\ T~ ~ ~\ _ R.!JE \. \ \ "- '''0 . .......... - --.. - -- - -Q- l ~ R6E FHE ReE R9E RIOE RilE RI2E \ R16E :II7E Fig. 2 - Isopach map of Ivishak Sandstone ("Sadlerochit"). in feet after, H. C. Jamison et ale Contours , .' r-:; tjDü" .f.C(r·11~'\~~'~\'EF.) ,j\UN 1 (i f:-"" '-~ ~u ~~~I. ... . .-....-..-. ) ) \'. : , ..... ,- -" .,.J ". ~ ¡Y.!?~ >. I.:. ¿0 o I r o ,. ~ .' .... .> ." ltiIIJII ... ..... , .500 ~ -------- 10,000 R6E RTE _ ReE 1--:' + ,.- + RgE RIOE RIlE RI2E R13E Fig. 3 - Structure map of top of the Ivishak 3andstone ("Sadlerochit"). Star symbols indicate wells known to have discovered oil in the Permo- Triassic reservoir section: (1) ~,lobil, Gwydyr Bay State 1, (2) Hamilton Brothers, Kuparuk Delta 51.2, (3) fIamilton 3ro~hers, Point Storkensen 1, (4) ARCO, ~Jorth Prudhoe Bay State 1, (5) ARCO, Gull Island State 1. Faulting is simplified here. Subsea contour intervals in feet after H. C. Jamison et ale ¡;;; 1" ;~, I" ~ I \:1 i~ ¡ '. \; \: lì ~\1 .¡: t,:> 2 (1 (I.D. 'ò2!\:9t-~t '¡ ~ ~ 1:=01..,,' 10' ,,1. ~ -~ ' -.'.' ) ) Subsection 3 Kuparuk River Unit - Kuparuk River Formation I. Injection Intervals A. Stratigraphy and Lithology The stratigraphy of the Kuparuk River Formation is depicted on Figure 1, which is a well log of water injection well lA-13. The Kuparuk River Formation is divided into an Upper and a Lower Member which are separated by an erosional unconformity. Unit D is a siltstone unit and Unit B is a sequence of interbedded sandstone, siltstone and mudstone. The reservoir sands are found in the A and C Units, both of which are believed to have been deposited on a shallow marine shelf during Lower Cretaceous time. The C sands are quartzose, fine to coarse grained, poorly to moderately well sorted, bioturbated, contain trace to abundant amounts of glauconite and are often cemented by siderite, particularly in the C-4 and C-l intervals. Varying amounts of dispersed glauconitic clay, siderite cement, and fracturing cause wide variability in C sand porosity and permeability. The iIo' thickness accumulation of C sand is in the CPF-l area where the Waterflood is taking place (Figure 2). The C sand bodies pinch out into the CPF-2 and CPF-3 development areas. Stratigraphic cross-section A-A' depicts the stratigraphy of the C Unit (Figure 3). The lowermost sandstone, the C-l sand, is thought to have been a transgressive marine sandstone which was deposited upon an eroded surface as the Cretaceous sea transgressed across the area. The C-l sand can be locally discontinuous. The C-3/C-4 sandstone body is interpreted to have been an offshore marine shelf sand which prograded out onto deeper water to the northeast. The Kuparuk A sands are more widespread than the C sands and will provide most of the production in the CPF-2 and CPF-3 areas. The A sands are quartzose, very fine to fine grained, and well sorted. The A Unit can be divided into at least six sandstone and mudstone packages which prograded towards the southeast, creating an imbricate stack of stratigraphically separated sandstone intervals. The prograditional nature of the A sands is illustrated by stratigraphic cross-section B-B' (Figure 4). The line of cross-section extends from northeast to southwest across the Kuparuk River Field (Figure 5). The A sandstone bodies are elongated in a northeast-southwest direction and are truncated by the erosional unconformity at the western edge of the Kuparuk River Field. Because of G-I C.~((·.··ÞII\~~~~~,:::I'I ~11 ü~\1: .,~ f'U~7 200D. \,,~I~}tJ i\~\.:, ~~L:-"" ,_:\,I~}U'J ..~'" '~~ ') ) the progradational nature of the A sands, pay zones overlap vertically in some areas of the field. The interbedded sandstones, siltstones, and mudstones for the A Unit are believed to have been deposited during storms on a shallow marine shelf. The Kuparuk River Field is a combination structural and stratigraphic trap (Figure 6). The depths shown on Figure are feet subsea, and faults have been omitted in order to simplify the structure. On the west, the field is bounded by an erosional unconformity which truncates the Kuparuk reservoir rocks. The approximate position of this truncation is shown by a dashed, scalloped line. The southern extent of the field is delimited by decreasing reservoir quality in the Kuparuk sands. To the north and east the limits of the oil pool are determined by the intersection of structural dip and the local oil-water contact (Figure 7). B. Formation Water Salinity Several wells near the Kuparuk River Field oil-water contact have begun to produce ~ reservoir water. Well IB-8 is producing water with a total dissolved solids content of 24579 mg/l. Similarly, reservoir water from well lC-l has 23494 mg/l total dissolved solids. II. Confining Intervals The confining interval above the Kuparuk River Formation consists of more than 2000' of Cretaceous shale. The lower confining interval is the Kingak shale, which exceeds 1500' in thickness. .-.... ~ ..., r.",:. 20n r: {.-"'f·l.l\~\J'~\~E·1 f-lF',; c _ H.': ,JI~.~~t\:·J l.' l,~. ¡ ~ _.- G-l o Gamma \. .. ~~ Resistivity 1000 Subsea' .neer. Uni, Mem. Kuparuk River Field Depth& va' bel D) Kuparuk River Formation ~.~~-.;-- We1l1A-13 ·ø·ç -~ : ';·~·ß.. s: C-4 'ß · ,., : ·:0' t: I li{<: J " ... '''G C-3 Q) <t.g f a.. c Q. '-.-. 60001 :) ,-..)::.:.:.~ . ~~~~:~ C-2 ~ ..~ .... . ~f - C-1 ..4_:. . ~ .~.... .,., tj, -;r: ., -""';- - ~ -, ""'" ~ G) ! I ff - 6100' t 8 ( , , , ~ - .c::::=: œ (J := :::: ... ~ ICe :::: QJ Z ==:~ A-6 ~ m~ Sandstone ~ t -:: ';, Î ~~ 0 m .... , -' .... .-. .. . A-5 '-/ r"l ~ ' .) ----.. ~ - c......... - £. :J,. 6200' II Interbedded Sandstone. ~~4 m~ ....... \ Siltstone. and MUdstone ~,~-~~ A-4 1~-' - A Ê~~ Siltstone ~,"p - f"'V '-- ~ c:::J \ - o MUdstone '=' .~--., A-3 - ~~ G'auconite ,- ~~- \ - êH Siderite Cement Fle;ure 1 6300' y - - ^' - Erosional Unconformity /~~ -- G) r~ - -....... ~ ( / CPF-2 FiL:ure 2 I , Waterflood Permit Boundary y CPF-3 , /~ CPF-1 ~ . A J Kuparuk River Field Kuparuk River Formation Unit C Net Sand 10' or Greater ~ ó c::;:, ("..j .;04 - ~ r~ 2~ ==. ~J =-~ "" ;~ ) ill 2? ~ ~ ~ ~ A SW 1 Y-I0 PROJECTED ALONG STRIKE I· "I 1Y-12 lA-lO - - lA-5 lA-B IZZ ZD:ø:z ZD :zzz zzz D2 DZ :zzz:zø az 'il ·J.¡.,.æ ZZZ ZZZ az z:zz. zzz -:z::z TZZ ,. ~ en -- ~ 50' FT- C~2 . ) ~ ,- ---'-" I f ,~ ~J I SCALE -- VERT _ EXAG :; 40. o . 2000' FT Pi1~ure 3 \-- \~ ~ \ "..,., - -- 1A-3 1H-B -, o="_~ t., ,_ ¡.", ~~. ~?~ ..:::-:-. ~)D· Û'~J '1 Y hi q Î' - i ~j \" h;./ - L.:: fj v~ ~t~!d .~. IH-6 A' HE ~C-4 ~ .~:z::¡ zzz I:::IZ:Z C-3 ~ --..:: 1H-l 1H·5 UNIT D - UNIT C C-2 , -.. C-1 z::z ~ - ........:«(, -"-.,,..------..-. - - .......... ~.,~. - ~".,- -,- ,,,,.,,,,, ", \ \~ UNIT B \ \ - - - - " ..........., - - -.....- (~ SIDERITE CEMENTED ZONES IN C-1 & C-4 INTERVALS D KUPARUK SANDSTONE INTERVALS WITHOUT SIDERITE CEMENT ~~ NORTHWEST-SOUTHEAST TRENDING FAULT y Kuparuk River Field Stratigraphic Cross-Section Kuparuk River Formation Units B,C, and D ~:p ¿J c::;J C"'-J t·." B NW WEST SAK 1116 ....~¡ =P .,;i=> ~d ~ WEST SAK #23 (PROJEC TED) UGNU ", 1Y-2 lA-15 S' SE IA-B r~ !~ 2-' :G -'r'- (r --- Û\ -------~-------~~-- -----...-....------- -- CD 50'_ FT. SCALE RESERVOIR SANDSTONE h o I 5000' FT. Jt'i~ure 4 Kuparuk River Field Stratigraphic Cross-Section Kuparuk River Formation Unit A VERT. EXAG. :: SOX ~" y /' /' -.. C) I -- -..0 ---... 1.1 i I': U 1'1--" ) / Truncation Of Kuparuk Lower-.... Member / ~, .; --- -",-. I I f ,. t CPF-1 / / -/ / ./ / CPF-2 /,,/ ;/~ ~ ~ ~ f ~~ ò c:::') c;-.w fi;~ ~ 2\ ¿:~ ='!! =4 =) ,-) íjJ L!! .~ 1'_/ ,~ Kuparuk River Field Kuparuk River Formation Unit A Net Sand 10' or Greater y Waterflood Permit Boundary r Kuparuk River Field Structure Map Top Kuparuk River Formation Waterflood Permit BounoClIY y ~!)aOO- _.r:,go<t ~. -.60a0f *" . _ .fô\oCf ~',.o<i _.»~o<t _ ~.oo- _,f}~oO ~. ~ =--:v ~ ~: UJ I L- I 1 <;~=; :2: . Truncation Of Kuparuk Lower Member <==' ~ '-'" ~:o c~ c::::J C"-! [.= II' i t~U ['0 () -- ~ ö C\ /-. - -7000 011 - -1500 Water - -1000 C' E... --5500 - ,-"'" c~-oJ !jJ Z' ¿~ ~ ·3 \~?; 2.': ::J) ~ ". t -~:-_:J ~ C) e, C'"+J 'f ! .~ ". Kuparuk River Field Structural Cross-Section Kuparuk River Formation .........-.--.. Dr'" Site 1E Figure 7 Stratigraphic ( Units: , 2 Mile I -7000 - V....E..g. = 20. ."øI~_ ¡>- P -8500 - (J) C West -5500 - /.f~..,-_ ) y ) SECTION H Well Logs 20 AAC 25.402(c)(7) 20 AAC 25.252(c)(5) All openhole logs from Kuparuk wells are sent to the Commission as the logs are completed. A type log for the Kuparuk River Field is attached in Figure H-I. Ii>' H-l . T-¡--' II j If\ f¡ <I 1"":( 200 A ~~I~ (J-d~~ ~~ c:. L, ,-h~ r~ .~ l U':J' o Gamma Ray 150 1 Resistivity ~ ~,_~)t~ II ;ç::.~:~~j:~~~ .ð -..... ~ ~ -~ "' (.../ ~ ~ ~ ~ '\J ~ }i ~ ~~~ I~f @:; ~ ~ \ 1000 Subsea Inter- Unit Mem- Kuparuk River Field Depths val ber D) Kuparuk River Formation Well 1A-13 C-4 ~ C-3 Q) a. - c a. 6000 ' :) C-2 C-1 l "f. ~ .....""> r ~::::;'~:':.:::¡:"t ~~!i ~~è' . "' ~1~~, ~ I ~ c:=:) J,;~:{~~ffi - - ~~ - 6100' B - 6200' A-6 ") A-5 ~ Q) ~ o ..J A-4 A A-3 - 6300' y ~~ C~) C) ç...j ~":~ r-'""l 2~ ~~ ,.:r-.;ß ~~) ,-~\ tLJ ~ 2: '1: ~ CIf) ~~~i~{~~ Sandstone :..:::-::;.~ E3 Interbedded Sandstone, Ë3 Siltstone, and Mudstone ~~~ Siltstone D Mudstone I GGI Glauconite ~ Siderite Cement }\ ....cJ C Ä1 (' ~ I -^-- Erosional Unconformity \ l i SECTION I Casing Infor ma tion 20 AAC 25.402(c)(8) 20 AAC 25.252(c)(6) Kuparuk Field development wells are cased as per the following Figure 1-1. This casing program is applicable to all wells except these cored in the Ugnu or West Sak formations. In these cored wells the casing is set~ 500' shallower and the casing is slightly bigger. API casing specifications are included on each drilling permit application. All casing is cemented in accordance with 20 AAC 25.252(b). ~ 1-1 \ "H,IN 1 ? 2004 ,I ) WELLBORE SCHEMATIC hj u~~ I-.1. I a Q [þJ: =On ... ........11head ....... ~ --- Ground LE'VE'l --- -- L ~... Conduotor @ go' ..... mject'ion Annulus '" ~""""'~~'''~ ~gnu Format'ion l¡mmmm~mmmmnmH¡¡Hmmmmmmm WE'st Sak Formation / L.. ~ .... Sur-facE' Cas:in9j!~ 200' MD bE'lo\Y' base of West Sak test~d intE'rna 11y to 2000 PS I ~~ L ~ .... Production Casi"9J~ 200' ~low base of KupMUk testM interna 11y to 3500 PS I C'.. Ie ,", IÓ· ~ ~~. q '.J" i fr- I·.·.·.: PUi 1\:; -', "7 ) 0: Uu \)WhUÎ,)ô\lB:.L; ...;' hi J. "L I ; i , SECTION J Injection Fluid 20 AAC 25.402(c)(9) 20 AAC 25.252(c)(7) IIeI () The injection fluid for the ~ types of injection at the Kuparuk River Unit are: t:if¡. tMf e ~ J ru ( (/ tJ-()J, 1 subsection 1 (page J-O watorflood, . d IS ð() ,,1 ~ Uit,d, 6f"'"fJ{A J' ¡. 1-0 I-t..( ru,...t';t.( ~tI ('"~;-",. ""'.'''J~' W,'14 subsection 2 (page J-6) pro~ú~d \V<\~E"r disposal, and ?1Q,," iç J.~cI.IIS I>J (.5k ¡"let/Is ~1'_ WI. SUÇ;)~II 3 (paßo ~ ) annulus~€tiQ¡(. PIt,"t- tJ,4.,,.~'¡"""'1 Subsection 1 Type of Fluid - water Analysis of Composition of fluid - attached Source of fluid - The primary source of injection fluid is Beaufort Sea water handled through the Seawater Treatment Plant. In addition to this, water that is and will be produced from oil producing wells will be reinjected, and minor amounts of Cretaceous water produced. fr_om the Ugnu water source wells will be used for makeup in the produced water injection }1.f.¡ te¡:.f lo,,(f · I1J+..Mltul ß,(()K! >' system. Estimated Maximum amount to be injected daily - 60,000 BWIPD, when produced water reaches 300,000 BWPD. Compatibility with formation and confining zones - Water sensitivity tests on core samples showed no significant problems with formation plugging or clay swelling over a range of salinities from 5000 ppm TDS to 100,000 ppm TDS. Water compatibility studies have indicated a tendency of mixtures of Beaufort Sea water and Kuparuk formation water to precipitate barium sulfate or calcium carbonate scale. Therefore, Beaufort Sea water and produced water are handled in separate injection systems. Cretaceous water is compatible with produced water, and has been mixed in the Increment I injection facilities since March, 1984, with no problems. J-1 r.... '.-. 1\ I\~i\! it: I'·'· H I I r\~ -,' t."'i 2 On" ~,~'}J(~,t ~G <\ ~ j l~-nt C'\;" ,j ~¡; \L; ~ ~~ JL é: .i' ,f"! J / Type of Fluid - gas Analysis of Composition of fluid - see Figure 3-4 Source of fluid - Estimated maximum amount to be injected daily - Compatibility with formation and confining zones - 3-1 ) ,.. .s,r;/\~\I;\"F~-·\ JI'I '~1. :1 7 200,~ ~~;. -:\:~J ...j ~~ ~~.".~' ~\ ~'C' j ~ .,'!. '.... ,l"f I .. ~ · · · · · · · ~ · I I · · · I ~ W ~it Table 1 PRODUCTION PROFITS DIVISION OF SONICS INTERNATIONAL. INC. Petroleum Service Laboratory DALLAS, TEXAS ) \ , ) Client f1~CO f1LACKf1 I NcOnrOnr1 TED County ANrHnRra{:;f lease Depth T I'll F"T Tn SIIPPI by Field K u par u k Formation Cretaceous Source of Sample ~nIIRrJ:' {vraTF=R Date Collected 09-,?Q-RI,I State AI 4qK A Well No. Perl. V WATFR TANK (Cretaceous) REPORT OF WATER ANALYSIS Lab. Number Total Dissolved Solids R.O. A'RSFNT {:;.J - \1 OC:;;9 Specific Gravity ?c:;;.., 1 Resistivity (Ohmmeters at 68- F.) 1 _ on 1 0 pH 4 _ ? Hydrogen Sulfide DISSOLVED MINERAL ANALYSIS PATTERN 10 20 l' 10 , 0 , 10 l' 20 N a 1""111I1111"1111I1111111111111"11111111 "1111I1111I111 "II" 1I1I "11111111" I" -II "'111111"" II" I" 1111" 11"1 t 1111'111111" I" "III "1"1'1""1111I11"11""1'" 1"11111"11111111111"'1 ClIO t c. HfII,"~IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIHHj¡.~,"I~HHHH 11111""1""1111I1""" 11""1""1"111111111111111111"111"11 ~1II11I1I111IIHHtm HCO. M g "1111111111"1""1""1""1""1""1""1111I ~ IIIIIIIIIIIIIIIIIIIIIH~ "11"111111I1 ~ ., ""1""1""1""1""1""1""1""1""1""1""1""1""1"" ~ 11I1111111111111111"11 SO ,1 1 1 Fe II" 1111,11111111" I1111111111111111111I111111111 L 11111111111111" 11111'11111' 1'1111111111' IIIIII.~ "1111I1",, 1111I1"" 1,1 "I III 11""11,, ,I"" 1111I1111111111111111111111111111111111111111111I1 CO¡ (Number Below Ion Symbol Indicates meq/ Scale Unit) 1 DISSOlveD SOLIDS ANALYSIS PRECIPITATED AND SUSPENDED SOLIDS ANALYSIS mg/I meq II mg!I Total Solids (Calc.) ?~?1 Total Undissolved Solids 1 Sodium (Calc.) R49 :\A.9 Oil (Solvent Solu ble) .3 Iron (Dissolved) 0 () Acid So/ubles .4 Barium ,3 0 Iron as Oxide: .18 Calcium 1.3 ~- 1 Calcium as Carbonate: .14 Magnesium 9 .7 Magnesium as Carbonate: .06 Chloride 17:\0 ~4.7 Sulfate as Bicarbonate ~.I-.6 A Unidentified: .03 Carbonate 0 () Organic (Ignition loss) .2 Sulfate 1 0 Acid Inso/ubles .1 Sand & Clay Barium Sulfate (Quan.) TOTAL IRON 1 (Qual.) SOLUBILITY CALCULATIONS Calcium Carbonate Stability Index at 77° F _ ,';4 Scaling Tendency POS Calcium Sulfate Stability at "95°F Concentration 0 meq /I. Calc. Solubility 77 _ 71ñeq/l. Percent Saturation ,.) Barium Sulfate Stability at 95° F Concentration n meq II. Calc. Solubility KIùÚfll. Percent Saturation 0 REMARKS J ...,:l. ,SC/'iNì;\jEC JUN 1 ? 20C]¿j .~ " - J J . - I ) ~ ~ - . . . , - '- e , Table 2 > PRODUCTION PROFITS DIVISION OF SONICS INTERNATIONAL. INC. Petroleum Service Laboratory DALLAS, TEXAS CII.nt FI.,,, K u par u k Form.tlon Source of Sam pl. ~I=~W!J.TI=R Dat. Collected 09-?R-R1 nnCON_A~Kn INCCRnonnTEn County ()NrHORnr.:r lease Depth by REPORT OF WATER ANALYSIS ì State (). ¡ì~~"J) We" No. Pert. lab. Number Total Dissolved Solids r:;.J -(J 0.1-.0 "7Rr:::,7 Specific Gravity Resistivity (Ohmmeters at 68· F.) 1 . 0':'00 pH LAB . ::U:::;C; Hydrogen Sulfide AR~I="I\IT 20 l' , DISSOLVED MINERAL ANALYSIS PATTERN , 11111111111111111111111I111"11"11111"111111111 T 11I111I11111111111111111 C I 100 10 l' 20 10 o N a fml""llllll"",m, 111"lIlllil"111ll11" 111111111111111111111111111111 100 ..., -- I . / '11I1'11I1""1'11I1"111""1"111"1111111111I11'1"11111111111111111111111111111111 .11111111 . 11111111111111111111111111111111111 I1111 111111111111111 11111 1111111111 ~IIIIIIII 1111111111111I1 H CO a 10 111111111111111111I11111111111111I111111111111111 ~IIIIII 11111111111111 I 11111111111111111I1 11I1111I11111I111I1111 Wllllllllllllllllllllllllll"llllllllllllllllllllll ~IIIIIIIIIIIIIIIIIIIIIII SO. 10 c. 10 Mg 10 Fe 10 1111I111I11I 1111111'11111111111111'11111111111111 LIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII I "'111111111111111111111111111111...111111111111111111111111111111111111 LIIIIIIIIIIIII'IIIIIIIII COaÞ- (Number Below Ion Symbol Indicates meq/ Scale Unit' 1 Q DlssnL VeD SOLIDS ANALYSIS mgll meq / I Total Solids (Calc.) ?7R!=.7 Sodium (Calc.) RR40 ~M4 . .~ Iron (Dissolved) 0 0 Barium 0 () Calcium ..,....4 1A.7 Magnesium 9Rl R(1. .l" Chloride 1:=;400 4~4.~ Bicarbonate 1 ...,.., ? Carbonate 0 n Sulfate ?1RO 4~~~ TOTAL IRON SOLUBILITY CALCULATIONS .:) Calcium Carbonate Stability Index at 77· F Calcium Sulfate Stability at 95°F Concentration 1 ,t.,. 7 meq / I. Barium Sulfate Stability at 95· F Concentration 0 meq II. REMARKS PREl"IPITATED AND SUSPEND en SOLI os ANAL YSI$ Total Undissolved Solids Oil (Solvent Soluble) Acid Solub/es Iron _as Calcium as Magnesium as Sulfate as Unidentified: Organic (Ignition Loss) Acid Insolubles Sand & Clay Barium Sulfate -.':"'t Calc. Solubility :=¡~. Ofrleq/I. Calc. Solu bility 0 meq / r. SODIUM BY AA: 9550 J -3 mg/I 2.16 o .46 Oxide: Carbonate: Carbonate: .09 .16 .21 o .1 1.6 (Quan.) (Qual.) Scaling Tendency ~~ ;:: ¡, Percent Saturation 3C. "'\ 1 Percent Saturation t) SCAli~NED JUN 1. [J 2DD~· I ) . -. · I · · I I ) · ) · J - I I · · I · I , , Table 3 l ì PRODUCTION PROFITS DIVISION OF SONICS INTERNATIONAL, INC. Petroleum Service Laboratory CALLAS, TEXAS Client AR~n AIARKA IN~nRPnRATED County ANCHORAGE lease Depth PRODUCED WATER OUT OF COALESCER 09/28/84 ~ State ALASKA Well No. Perl. Field K u par u k Formation Source of Sample Date Collected REPORT OF WATER ANALYSIS Lab. Number Total Dissolved Solids 8,)-4061 13704 1 . 0104 pH · 52 Hydrogen Sulfide 8.4 ABSENT Specific Gravity Resistivity (Ohmmeters at 68- F.) DISSOLVED MINERAL ANALYSIS PATTERN 20 l' 10 " 0 , 10 l' 20 1 00 N a r "'1""1 "" 1""1"'1" "I "" I "" 1""1"" I" "I" "I "" I' "'I'" 'I" "I"" I ''''I\,' "'\"" I' '" 'I "" r "'I"" I"" I" "I"" I "" I "" 1""1" "I" "1""1""1""1' "'I" OIl ell 00 Ca 1111111111111111111111111111I11111111I11111111111111111111111111111111111I~~"~IIIIIIIIIIII 1111111111111111111 '11111111111111111111"111111111111111111111I11111 ~ 11I111111111I11111111I1 H CO}) 10 1_ M g m$Hjtmll.IIIIIIIIIIIIIII»HtUlIIIIIIIIIIIIIIH"~m~lfm+lm+lml 11I1IIIIIIIIIIHft~II" 1111I1111I1111I1111111111111I1111111111111111111I 111I1IlIlIftm so. 10 10 ~ Fe 1111111111111111111111111111I11111111I1111111,111 ~IIIIIIIIIIIIIIIIIIIII 1111111,1111111111111111I1' 1í1l11l1l1"lllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllIIIIIIII~III COJ 10 (Number Below Ion Symbol Indicates meq/ Scale Unit) 10 DISSOLVED SOLIDS ANALYSIS PRECIPITATED AND SUSPENDED SOLIDS ANALYSIS mgll meq II mgll Total Solids (Calc.) 13704 Total Undissolved Solids 859 Sodium (Calc.) 4880 212.2 Oil (Solvent Soluble) 782 Iron (Dissolved) 0 0 Acid Solubles 18 Barium 13 ., Iron Oxide: 3.02 ..L as Calcium 18 .9 Calcium as Carbonate: .77 Magnesium 9 .7 Magnesium as Carbonate: 14.21 Chloride 5900 166.4 Sulfate as Bicarbonate 2860 46.9 Unidentified: 0 Carbonate 14 .5 Organic (Ignition loss) 15 Sulfate 10 '") Acid Insolubles 44 ."'- Sand & Clay Barium Sulfate (Quan.) TOTAL IRON ,., (Qual.) .L SOLUBILITY CALCULATIONS Calcium Carbonate Stability Index at 77° F 1.06 Scaling Tendency P~S Calcium Sulfate Stability at 95°F Concentration .2meq/l. Calc. Solubility 46.. 6meqll. Percent Saturation .42 Barium Sulfate Stability at 95° F Concentration . 2meq II. Calc. Solubility . 1 ~eql'. Percent Saturation 100 REMARKS .J -4 n ¡l~\ "", \"';' 2Drn <)1 ~\,.j ~ ~ )~, J _ :.;1'-0 '\ / ì Figure J-4 Gas Analysis Property Value Nitrogen .24 MOL% liMe thane 85.29 MOL% Carbon Dioxide .94 MOL% «ethane 7.43 MOL% Propane 3.95 MOL% Iso-bu tane .56 MOL% N-butane 1.14 MOL% C6+ .07 MOL% Hydrogen Sulfide *** >- J-l ~~ ,.f\JN 1 (" 20D¡~, ~ l ì Subsection 2 ~eeá·-Wator Dispo~~l ~Ielt;¡ 0, :./,() SÞR '¡'-"o".- Type /I Source - The injection fluid at the -produced W.iter disposal w:eHs is predominantly produced water. The injection stream includes drilling mud, reserve pit water, contaminated crude, diesel gel, glycol, domestic waste water and workover fluids. Only Kuparuk River Unit generated, nonhazardous fluids are injected. Estimated maximum amounts to be injected daily - 4000 BFPD. ~~~,- f1....n:!.çtr.~ Þ:f~-t;on . I hazardous waste be injected illing muds and cuttings take either rig or during e summer months. The volum of fluid injected will no bbl per well averaged over th otal number of wells on the pad. ~ luids injected during annulus injection operations incl l. 2. 3. 4. 5. 6. J-1 ~~jCrÜ~~ ~\J ~c:: C ¡ I ¡ ~:i -; ¡~;? In f'I;1 . .. ~ 'oJ ,Ud J _'~ L L ~~'k.''-B'" j ) SECTION K Injection Pressure 20 AAC 25.402(c)( 10) 20 AAC 25.252(c)(8) €IA ¡,,()"C~ I (-J'êo{)<A , The maximum wellhead injection pressure for Wiltcf injection wells in the Kuparuk River Field is 2550 psig. This pressure is the maximum discharge pressure of the injection pumps. The average injection pressure in the Field is estimated to be 1800 psig. HGJ(.ù ~ j04- ~ J.I( .¡./)¡.. S' ? The maximum wellhead pressure for ¡¡,raduo...~ w....t'€'r disposal wells in the Kuparuk River Unit is 1200 psig. The average injection pressure is 700 psig. Ttw ,ncixirnurA wcUhcð.d pr~s!urc for annulus injection is 2000 pGig. The ~vpr~~ inje('tLn~ >- p.r.essure ic; 600-700 pgi6. " J-1 SC;:'~~¡2NF;;- ~t If\r, '1 ,"";; r¡OO 1 .......... "'" ~1Jj ...:.. !I L\..' J",' J } SECTION L Fr acture Infor ma tion 20 AAC 25.402(c)(11) 20 AAC 25.252(c)(9) The proposed maximum injection pressures will not initiate fractures in the confining strata which might enable the injection or formation fluid to enter freshwater strata. Subsection 1 W'Ml ~ .Ho!à/Enhanced Recovery Injection in the Kuparuk River formation, above formation parting pressure, may be necessary in the future to allow for additional recovery of oil. In no instance would sùch injection pressures breach the integrity of the confining zone. The Kuparuk formation is over lain by 3000 feet of confining shales which act as an impermeable confining zone. Any fractures which may occur in the injection zone (Kuparuk River formation) would be confined to that zone and would not significantly penetrate the confining shales. Increment I water flood performance and pressure transient testing in the CPF-2 area has strongly suggested that preferential flow exists in the north-south direction. Any fractures induced by injecting at or over, injection pasting pressure are not thought likely to effect this tendency and in fact could reinforce it. This could have a positive effect on water flood efficiency based on the line drive configuration of the water injectors along the same axis as this directional preferential from trend. The Kuparuk is separated from producing horizons and water bearing zones by over 3000' of confining shales. These shales provide a substantially greater barrier than necessary to contain fractures within the Kuparuk formation. J-l ~íljrii\¡ 1 [;ï ?on/j r<J!1I.-~J .~, ,I __..í..,.',j" ) ) ».., Subsection 2 ar 8 J J 1 j 1~ ~r Disposal Subsection 1" Press e integrity tests below surf ce casing below t e West Sak have a formation arting pressure of + -0.65 psi/ft. These s not purp sely fractured during injecti n operations; howe r, if inadvertent fr turing should occ r, these formations are suffi iently isolated from exempted aquifer str prevent inf! into these strata. The injection z ne is separated from the exempted aquifer 0 take by 200 confining slate. In' ction pressures are less th hat would be req . e confining strata. J-l l"· t' í fl'\ - '",~¡çr" p ~N~! / ¿I kh' ~SCl\NJ11J~l.. ,\., . .'1 ,. ~ ~ ~ 'w " l SECTION M Formation Fluid 20 AAC 25.402(c)(l2) 20 AAC 25.252(c)(lO) ) A water analysis for the Kuparuk River formation is included as Figure M-l. A water analysis for the lower Ugnu is A calculation of water quality for the zone 200' below the base of the West Sak J-l :Ii" P jM -:¡ ~:. 2nfi 'I. (~, 1~....: ð 'J '-~~ { _ f..,. ~...>'~J 'J J PRODUCTION PROFITS DIVISION OF SONIC$ ImRNATIONAI.. INC. Petroleum Service Laboratory DALLAS. TEXAS ~ ',~ <4 Table 4 CII.nt FI.," KIIP~RIII( Formation Source of Sampl. ;¡7~R..-1'4 WJ:'I I Date Collected 0 I ¡~~ I I NconronnTLn County Lease Depth ttr-l I n'"J:'~ by . nnco "LnûKi\ ) 1-1J U R e fJ1 -1. fìN'"'HOR"t;E State "J {)C:V~ Well No._ Perl. AANO REPORT OF WATER ANALYSIS Lab. Number Total Dissolved Solids r.:·1- ~ O.J...":' ?1C;1C; Specific Gravity Resistivity (Ohmmeters at 68- F.) 7_R û.'R~:U=NT 1 Q 1 77 pH LAB ?R Hydrogen Sulfide DISSOLVED MINERAL ANALYSIS PATTERN 20 l' 10 , N. fllll""IIIIII""I"" 11I11.."1....1....1....1""1""1.." 1111I'''"1'''''' 100 o 10 l' 20 , mecr II ~RA_7 o _7 ~-4 _A ~~?_R AO_!=:; o ?!=:; III r 11111" '1111I111111111I1" 1'1""'11I11" "'" .,....,'...'.............., CI 100 C. IIIIIIIIIIIIII~IIIIIIIIIIIIIIIII'IIIIIIIIIIIIIII~IIIIIIIIIIIIIIIIIIIIIII ~IIIIIIIIIIIIIIIIII 1-11I1111I111111111111111111 111111111111111111111111111111I11111111111 ~IIIIIIIIIIIIIIIIIIIIIII H COI 10 M g , ""IIII'IIIIIIIIIIIIIII""'lm'Ill~""'''''~IIIIIII''II'''' "'I'" 'I" "I"" 1""1''''1'' I 111I111111'11I1111111111111I1111111111I111111"" I ""1'" II,ml'''' t"'l,mllnl'llll"n SO. 10 SODIUM BY AA: 9580 10 Fe 111111111111111111111111 11111111I1111I1111I111111 ~ 11I1111 1111111111111'" L I" I"" I" II I,", I" 1...111' 1111I1111111""1,,"1 111111111111"1,,"1111I11111111111111,1111' LII 11111I1",,1""1,," eOa (Number ae/ow Ion Symbol Indicates meq/ Sca/. UnitJ to Iw PREl"IPITATEn AND SUSPENDFO SOLlOS ANALYSIS Total Undissolved Solids Oil (Solvent Soluble) Acid Solubles Iron Calcium Magnesium Su Ifate as Unidentified: mgll 55.54 4.65 8.71 3.46 .29 1.22 3.74 5.45 36.73 10 to DlssnLVED SOLIDS ANALYSIS Total Solids (Calc.) Sodium (Calc.) Iron (Dissolved) Barium Calcium Magnesium Chloride Bicarbonate Carbonate Sulfate mgll ?4!=:;4~ RRQO o 4~ 109 7 1 1 ROO ~~qo o ~ TOTAL I RON SOLUBILITY CALCULATIONS Calcium Carbonate Stability Index at 77- F Calcium Sulfate Stability at 95-F Concentration - t mecrll. Barium Sulfate Stability at 95- F Concentration - 1 mecr II. REMARKS asOxide: asCa rbona te: asCarbonate: ~ 1 Organic (Ignition Loss) Acid Insolubles Sand,. Clay Barium Sulfate (Quan.) (Qual.) -.1,-73 Scaling Tendency NFG Calc. Solubility r:=:.r..,. _ Aiieqll. Percent Saturation - 17 Calc. Solubility . i1åëq/I. tno Percent Saturation m-2- :S(~/\NNE~:\r ·jUN J ? 20Cc~\ ) ) SECTION N Aquifer Exemption 20 AAC 25.402(c)( 13) 20 AAC 25.252(c)( 11) All aquifers or portions of aquifers lying below and within 1/4 mile of the Kuparuk River Unit are exempted aquifers for Class II injection. (ref. 40 CFR 147.102(b)(3) and 20 AAC 25.440(c).) .. J-l ~~~cr: :~ 'IN .-;¡ fry 2no'~ ;,:; t...... ~,',,' 1:. J ~.) II '. ..L. d .:;; - '-J" '" ) SECTION 0 Hydrocarbon Recovery 20 AAC 25.402(c)(l4) ) Total expected hydrocarbon recovery from the Kuparuk River Field is 1600 MMBO, or 30% of currently estimated oil originally in place. Of this amount, 1067 MMBO, or 20% of OOIP, is attributable to waterflood. J-1 ". 'IP í~~ ·1 ? 2005 ~,.' r,' I!,J ~ ~1 _'" ~! ..\.. iJ ) SECTION P Mechanical Integrity 20 AAC 25.402(d) 20 AAC 25.252(d) In newly drilled Kuparuk wells, the casing is pressure tested in accordance with AAC 25.030(g) (see also Figure 1-1). If converted to injection, the casing is again pressure tested in accordance with AAC 25.412(c). The casing annulus pressure is then monitored on a daily basis and recorded by the drill site operator. The reporting requirement of AAC 25.402(d) is addressed in the variance section. . J-l sc·t\,:~,~ ~j E ~=. ~!) ':' 2 0 C"~ ) SECTION Q Wells Within Area 20 AAC 25.402(h) 20 AAC 25.252(h) ) The wells within the area of review (i.e., Kuparuk River Unit) are shown on the plat (Figure B-2). To the best of ARCOAlaska, Inc.'s knowledge, the wells within the area were constructed, and where applicable, abandoned to prevent the movement of fluids into freshwater sources. J-l s~ f,;l\ t¡'"J ~\!~:T'· n '¡ \\ 1 -:] ..'.s .. ''-I',' 'V ~;, I...,· ", ~ It~. I' tl _,,~. .. 7 2004 ) )1 SECTION R Variances 20 AAC 25.450(a) ARCO Alaska, Inc., as operator of the Kuparuk River Unit, requests variances from the Oil and Gas Conservation Commission rules. Variances may be given, at the Commission's discretion if: injection is not into, through or above a freshwater of nonexempt freshwater aquifer, and injection does not result in an increased risk of movement of fluids into a freshwater source. .. The aquifers underlying the Kuparuk River Unit are classified as exempt aquifers by the U.S. Environmental Protection Agency and by the Commission. Subsection 1 Monthly Reporting of Casing-Tubing Annulus Pressures Kuparuk wells are not equipped to monitor the casing pressure on injection wells automatically. These pressures are recorded daily on every well by the drill site operator. This data is maintained in a paper database by ARCO. The daily check of casing pressures is to verify no communication exists between the tubing and the casing. Prior to initiating injection into Kuparuk wells the annulus is pressure tested to ensure isolation of the tubing and casing. Since current plans call for up to 400 injection wells at Kuparuk, with a potential to double that number if infill drilling is initiated, it would be a considerable task to report the casing pressures monthly as requested. It is requested that Kuparuk maintain the paper database for the Commission's examination and that ARCO report to the Commission any wells which have a casing pressure change of over 200 psi while under normal injection operations. Due to the temperature variations involved in the Water-Alternating-Gas (W AG) process, it is anticipated that casing pressures will vary considerably. Since it is possible that a 20OJf)5i change in casing pressure may occur with JUN 3. 7 20011 ) ) i. ~ each cycle change, plans are to inform the Commission of pressure changes greater than 200 psi after the casing fluids have seen the thermal response of the WAG cycle. '" Subsection 2 Annulus Injection A J-l ~·.·r I·, ~,I \~\ cr! .n.JN 1 ? ZO [\( ~ ,J. 'i;..,J' 'I..r, \ ' \. [~".., 'f, ~\ ') 'ì) )' CIIE¿~lICAL & GEOLOGICAL LA BOR.;:1 TORIES OF ALASKA, I1\rC. P.o. BOX 4-1276 Telephone: (907) ANCHORAGE INDUSTRIAL CENTER Anchorëge, Alaska 99509 562..:..2343 5633 B Street ~~~ 6p~ WATER ANALYSIS REPORT Alaska DAT~ July 8, LOCA TION FORMATION INTKRV A ,. SAMPLE FROV . 1983 LAB HO. 2837-1 OPERATOR ARCX) Alaska, Inc. WELL ICO- FIELD COUNTY IT A T"I Kuparuk wsw-2 U~8 4- C'ONCLtl.JIONa~ Bar1.urn (Ba), ITg/l ----------1.::, Strontium (Sr), ng/I --------0. H4 Iron (Fe), ¡rg/I -----------ü.:¿b oil & Grease, rrg/1 -----------3.0 'furbidi ty, ntu ----------------2. 7 Suspended Solids, ¡rg/1 -------16 Dissolved Iron, mg/1 ---------<0.10 ~ .st!! .æi!! ArJona s!1 ..!!!9!.! ".At" no - - - - - 91r:; 39.82 Bulb te - . . - <1.0 0 P-....,..~ 4.6 0.12 CbJoride . - 1280 36.10 r,,~ - 48 2.40 CuboGate 0 ~Wr.0..4 7,9 0.65 BJ.carbonata - - - - - 420 6.89 Irca . . ----- H;rdrox1de - - - - - 0 Tcrta1 Catioat 42.99 Tot&) An!ooa - . . . 42.99 - - -..-.- .. - Total c!!ndnd IIOUdI. mall 2463 sped&: ~ @ ~·P.: H&Cl eqcz!T&lœt, q:/l . . - . - - - 2375 O~ .',:; - - - - 2.5 ohm-lDIÚft Oll r<. J.d pH - . . . - 7.8 CrknL,t:.d . - - 2.8 akm-...... WATER ANALYSIS PATTERN sw. Sample abov. dncribed MEQ per U aft j I ~ Ca' I, , ! "WI' II! i' ; , ¡ ¡ I ¡ t I ,j HI I,", ¡ L! .! j : I i, j'! 'ij " ,J' I ' ¡t: ¡j . d ·L " 'j f; H .! ¡ CI 10 N. ¡ \' I ··HCO~ 1 Ca , l' I 1 q so. 1 Mg ¡: . . !,' '~CO. 1 Fe , ~' 1 . I ! I' ¡ 4-:-- >" t!:r;: C I : :,-:~!:,-r Na , HCO:. . . . . I HE ~ - ~r . . I I t' 1 . , Fe ::-'( '~1~~ :.:. -. j . f ,I ~;': t ï· ¡,. -W-I! ! ! ~ , ¡ 804 co. (x. ft1ae fa ~ ~ ...... x.. a:. ... U) J(OT&: Kc/1=Ji[~ p. kr K"4/I= -œIcna ~ pc- 1l..- a.ð:a ~ ~:=w 0-.. · H~ ~ ŠCl~NN\::e' JUN 3. 7 2DOl1· OPEUTOP WELL 110· FIELD COUNTY STATr ') CHE!fICAL & GEOLOGICAL LABORATORIES OF ALASKA, Il'lC. P.o. BOX 4·1276 Anchomge, Alaska 99509 ANCHORAGE INDUSTRIAL CENTER 5633 B Street Telephone: (907) 562-2343 WATER ANALYSIS REPORT ARCO Alaska, Inc. DAT~ July 8, 1983 LOCATION Kupa ruk FORMATION INTERVAT. Al aska SAMPLE FROV.. WSW 7 LAB HO- 2837-6 nJ!A.JtX8 a CO~CLUIIOHI! Barium (Sa), mq/l ----------------1.1 Strontium (Sr), mq/1 -------------0.67 Iron (Fe), mq/1 -----------------<0.10 Oil & Grease, mg/1 -----------0.74 Turbidity, ntu ---------------1.2 Suspended Solids, mg/l ~------4.0 Dissolved Iron, mg/l --------(0.1Ô ~ .EI!! ~ ALJona .!:I!! .!!!Sl! s.~J.u.\ - - . . - 830 36.11 8 a1.fa te ""-1 . 0 0 Pot-o~ 4.6 0.12 Chkcide . . . . . . 1240 34.97 c-tk4- - · . - . . 59 2.94 Cubooate 0 ..·I·L....l~ · . . . - 6.8 - . 0.56 BW:ubonate .... - - - . . 290 4.76 Irca - - · - . . - H;rdrodde . . Total Catlo:ol 39.73 Tota] A.nJoca . . . . 39.73 -- ----...- Total ~ ~ mUl 2283 speciB.c ~ @ õð-P.: HaCI eq~ r::cIl 2223 O~....,ul:r . . . . 2.8 ohm-lI:IIItIft Obut..:" pH . . . . . 8.0 Cr \("n1·t. d . . . 3.0 ot:m-.... ¡ ; ¡ 1 i'I'; Na ::1 i ¡. : ; 1 . 1 ¡ , ; ¡, Ca . '~: ," .'" i. ¡' , .. . t 2 _ I ¡. J ' . He :' ~ r.t 1 ~ í· " If' t ! ~'t F..,I·.·I . A ,I L . '1 ¡ . , ~, WATER ANALYSIS PATTERN Scale MEQ per Unit , &ample abov. det.C'ribed .' Cl 10 Na t Cl II HC03 I , L f' , so. ~ ' J . . I. i CO. . I' ,II ! ' ¡ " .. !! . I· 1.. ! j it ¥ : t ,,.~.~ t I ' I .11 11./. : , 1 ¡¡ ~ It I ' 'III! ¡! I' "Ao}! II' , ,I ! I I' I . I¡ t I., ¡J!d.Hi .11 HCO~ 1 c. 'S04 1 Mg I 'COs 1 Fe If . I I,' . (w..... III ~ t;nfk ~ Xa. a:. .. U) . on: Kr./1 =)(J!Içw=JI poll' 15ta K.qJ't = IiIIJIcT- eq~ pII' 1Lw a.K1as dÜori4e ~=~ t>--. . R~ ~'"""~ ~Ic.._ &ca.-, , -' SC:l\NNErJ JUN 1 7 2.GO~· ÎI ') '.) CHE1'fICAL & GEOLOGICAL LABORA TORIES OF ALASKA, INC. OPERATor WELL xo pmLD COUNTY IT AT~ P.o. BOX 4-1276 Anchor~ge, Alaska 99509 Telephone: (907) 562-2343 ANCHORAGE INDUSTRIAL CENTER 5633 B Street WATER ANALYSIS REPORT ARCO Alaska, Inc. DAT~ July 8, 1983 LOCATION Kuparuk FORMATION _ IKTERVAT. Alaska SAMPLE FRO1£.. WSW 8 LAB MO- 2837-7 It.J:JfA..Rr1 .t CONCLUfIOHII: Barium {Sa}, mg/l -------------1.0 Strontium (Sr), mg/I ----------0.65 Iron (Fe), mg/l --------------~0.22 Oil & Grease, mg/l -------------0.54 turbidity, ntu -----------------i.O Suspended Solids, mg/l ---------4.0 Dissolved Iron, mg/l ----------<0.10 Cd!=ca .sill !?5l! ~ .S!!! ~ - . . - - 790 34.39 Sulla te 1.0 ~-'- 4,6 0.12 Chloride - . . 1200 ('a.1d- - . . - 63 3.14 Carboa&te ~__I . 6.6 0.54 Bk:arbon&te 265 !rea - - - - - . . HrdroJdde Total C&&a. 38.19 Tot&) AnJoaa . . . . -- ~~- Total ~ d\4&, æUl 2195 Speci& ~ @ ~·P.: HaCl eq~ ~1 2140 O~ - . - . 2.8 O*n,;,d pH . . 8.0 CIIlc-n hot ~ I " - . . 3.1 I 'í I I , ¡: I I', ¡ ; I Na ~! j .; I' ! ~. ¡ C& . ; ¡, ~ ~ , , 1 t / I f ~ i "¡ ;; . & \.. 1.!¡' ¡ 1; ~ , 1 :: ,f ;! ~ ' F. , I' , . I:,:;' . ·1'· ~J';' ,. .!!5l! o 33.84 o 4.35 o . 38. 19 ob-lDRIn obm-~ i.·.~. ,,:c.,, ;1.-' L ~. , .1 \i¡- 1("'< ~ ' }-. i~ ~L- n ~} 1('" ¡1 J ~. 1..,....1 ~ ~ Ll. Alaska Oil & Gas Cons. Comrnfss1on , )\ X3n'll~ I, I, WATER ANALYSIS PATTERN sw. UEQ per Unit '--, , jUt. - íS Szmpl. abov a d e-ecnõecl .~ I I ,~ ':: ¡ i I Cl 10 Na ' I . HCO. 1 c. ¡ ' .I. so. 1 Mg P It! I 1 ; , 1 tll ! Ii I t j j , I ! II ¡- I ; I "'I I 1. ' , 1 " . II . t: 1 " . I y, I co. 1 Fe ! I t . ¡ ¡r ,,' , ! 1, . , !' , ;ì It (: , t '~ J-'_~ ,'(,,...... ~ ¡: , Cl HCO. ,~ ' S04 , t ;! w; ..co. (Ih.... hi ~ ~ ~ J(&, a:. ....t..I? SC-i\I\INE'··" ~UM -1 t"'I 20n ~ .on: JC&/1=Jf:1!iça::JI par h:r X-vt= .~ ~~IU\WI ' !',) .). !'j J., 1.\ ,,,it ~ ~ ~=~ D~. H~ ~~ &.. 1- ¡ -, ~- .,,1 T:¡' ?üo4 OP1tK.ATOR WELL ICO. PIELD COUHTT STAT. ) ) CHEJIICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. P.o. BOX 4-1276 Anchor<!ge, Alaska 99509 Telephone: (907) 562-2343 ANCHORAGE INDUSTRIAL CENTER 5633 B Street WATER ANALYSIS REPORT ARGO Alaska, Inc. DAT~ JulY 8, 1983 LOCATION Kuparuk FORMATION INTER VAT. Alaska SAMPLE FR01l.. WSW 9 LAB NO. 2837-8 UJ.'¡(ARXS .\ CONCLUSIONS! Barium (Ba), mg/l -------------1.4 Strontium (Sr)~ mg/l ----------0~84 Iron (Fe)~ mg/l ----------~----0.11 Oil & Grease. mg/l -----------0.93 Turbidity, ntu ---------------1.0 Suspended Solids. mg/l -------4.2 Dissolved IroD. mQ/l --------<0.10 Cri=s .æ~ ~ ArJon. 3!! ~ ~ .. .. .. .. 972 42.30 Sulla te .. - - .. - .. 1.0 0 I'v-r""'- .. .. .. . . 5.0 0.13 Cl11odd. .. .. 1440 39.48 r,~ - 61 3.04 Carboaate 0 Ib.ar:. · 7.9 0.65 Bicarbonate 405 6.64 .. -... !rea -. .. H7drozide 0 ToQJ Catloal 46 . 12 Tota} Amoaa .. - .. .. 46.1? --~..- To1a1 ~ ~ m¡¡Jl 2646 Sped.Bc ~ @ ~·P.: HaCI eq~ q/l 2560 ObeetT.c. 2.4 obm-m:=t=w Oham..wd pH .. .. .. .. .. -7.8 c~ lc-n tJ¡ tI d - .. .. 2.6 œm,.~ '.~ !j { 'J Ii I . . Nt· !q,. .P! ' r . f i " j : i ~ ' :. ! Ca : ¡: I ". .~ · : i! . j . ~ j " . . ' ... .,.. &' I' I .. . He' . d - ~.'~ . I. t· : r:PH¡. . t 1 . t I ¡ - ¡ ~ . I ~ F. ' '~I;;.. j ~. ' ' i ~ d I . If i - . -~.L J 1 ,:' WATER ANALYSIS PATTERN sw. Sampl. abov. deecnôed MEQ per UlÚt ¡ t : r .,~. . J I .. .: :,. ,. . .....,...,- ! . Cl 10 Na HCOa 1 Ca , Cl ~, L 'ttf I; ,lXI, I I . . ,,!Ill ; h . ; ; so. '"1 . . i r.·.· .. t .. 1 1-·~., I. -I ¡, :.. ~' . . CO, 'f i' ../1 l' -. Ih! -lid! ! I·¡ ; ,,' HCO, Mg 1 S04 I, 1 Fe . co. , . . f ' ¡ . ~¿liNNED ~jUN 1 7 2Dü,~ (Jr, --. ill ~ ~ ...... x.. ~ aa4 U) Jlon: )!c/l=J(~ I*' JItI;:r 111\/1= K~ e.q~ I*' 11.- ~ ~ ~::=..,. D~ . H~ s.....'t:.& &.a,- ,,- \_ ) ~~ ') CHE1'fICAL & GEOLOGICAL LABORATORIES OF ALASKA, I1\TC. P.o. BOX 4-1276 Anchor~ge, Alaska 99509 Telephone: (907) 562-2343 ANCHORAGE INDUSTRIAL CENTER 5633 B Street WATER ANALYSIS REPORT OPItUTOP ARCO Alaska" Inc. WELL 110· PIELD Kuparuk COUNTY STAT- A1 aska DAT2 July 8" 1983 LOCATION PORJ¡fATION INTERVAT· SA.MPLE PROV., WSW 10 LAB MO. 2837-9 JU:HAJUtS a CONCLUSIONS! Barium (Sa)" mg/l --------------1.4 Strontium (Sr). mQ/1 -----------0.74 Iron (Fe)" mg/l ----------------0.33 Oil & Grease, mq/l ---------------0.77 Turbidity, ntu -------------------1.4 - Suspended Solids, mg/l -----------5.0 Dissolved Iron? mg/l ------------(0.10 C&tIoaa 5.!! !?5l! ArJona 3!! .!!5!! k.,tt..".. . . . · 908 39.50 Sclfa te . <1.0 0 PoH-'M'i- · · . · · 4.7 0.12 C1ùoride .. .. . . . . 1280 36. 10 ('.~ . · · . · · 51 2.54 Carboaate 0 vsr-: ~ · · .. · · 7.1 0.58 Sk=ubonate 405 6.64 Iraa . - - · - . · HJdroxide 0 Totd Ca tIcJr» . . · · 42.74 Tot.a1 A1ùoca 42.74 ---...- Total c!i.moInd ~ mç,I1 . . . · · 2450 Specific ~ @ ~·P.: KltC1 eqDfTa1c:œt, 1D.'Ú1 · . . .. .. · · 2365 O~ - . . . 2.6 ~c=tId O~~ pH - .. .. · . 7.8 CJt 1('11 þI t II! " . . . 2.8 01:=-...... WATER ANALYSIS PATTERN sw. !.unp!. abov. describocl !IRQ per Unit ' , ' .,. I . f ¡ Na I 'I- C! 10 Na ' 1 '" Cl ~: ! I ¡ j . , ,-~ .. II ,¡';þ' ì i ¡ ! ;~. I ' I' ., I I . I: 11 1 I: . d 1./ HCO~ 1 Ca Ca.. . P .. ,,/. .HC03 I !' I '. ; III I ! ¡. 1 ~ ! . j I I' . -, ¡ ¡ ¡ 1 ¡ ti 1 ¡ I HI t I':. · jj. .."J [1' 804 1 Mg S04 i· ¡ I , ¡ I I F. :'!¡Iï' ¡,I1¡!111 II 'CO~ 1 Fe I . CO. ., -'J' I j j I 'f [ i ¡ I ,!n .: j 1.1 II] Il : {, t' . ' . , (x. ..... b ~ ~ ~ Jlfa. .:. ... U) ")~C-'I\ NI'NEn JUN "1 [J ZOO,} .on: J!&/1=K~ pc 1Ita .eøJI= .~ ~a p.r u~ n! L:- ¡¡ -- d ~ ~ ~=Þr DIIiIÚ:ip. H~ -1'-'~ &- .~""- ) ) CHE1~1IC..4L & GEOLOGICAL LABORA TORIES OF ALASKA, INC. P.O. BOX 4· 1276 Anchorcge, Alaska 99509 Telephone: (907) 562-2343 ANCHORAGE INDUSTRIAL CENTER 5633 B Street WATER ANALYSIS REPORT OPEUTOJt ARCO Alaska" Inc. WELL 110- PIELD Kuparuk COUNTY STAT'" A 1 as ka DAT~ July 8" 1983 LOCA TION FORMATION IXTERVAT. SAMPLE PROW., WSW 11 LA. MO- 2837-}Q UlfARJ:8 . CO¡CLU8ION8: Barlum (Ba , mg/l --------------1.3 Strontium Sr), mg/l -----------0.82 Iron (Fe), mq/l ----------------0.74 Oil & Grease, mg!l -------------0.49 Turbidity, ntu -----------------2.3 Suspended Solids, mg/l ---------2.0 Dissolved Iron, mq/l ----------(0.10 ~ .!SI!!. .e!9!! ArJona .!!!Ill .!!5!! ~n....~ - . . - q41 41.01 Sulfa te - . . . <1.0 0 ~ 5.5 0.14 Chkdde . . . 1320 37.22 C'.~ - 50 2.5 Cuboaate 0 K.~- · 1ft . . . 7.5 0.62 Bicarbonate 430 7.05 Irca . . H7drozlde 0 Total Cat5œe 44.27 Tota1 AnIoaa 44.27 -- ...-. -.- Total &so1Ted ~ =411 2538 SpeclBc nèstz.Dc. @ btI· P.: HaCl eqainlct, m¡/1 2447 ObeernG - . . . 2.5 ~1DIIt8rI O~..-.4 pH . . . . - 7.8 CJo¡\cnt't.d - . . 2.7 ca&m-~ WATER ANALYSIS PATTERN awe Sæ.mp]. abov. descnÞecl HEQ por Uait - ,I r Na .. ,:.~·t' 'I' I i.,' !!' ¡. ¡'IL Ca ,I: J .! j: .~ !: I ,!. ' , , . 'I"'" ¡ ì' ¡, ¡ '¡". J: ¡ . i ~r, ·,·ill ~ " ¡1tl ,l¡1¡' I ££1 1· "II' :,..41 ¡ ': .' · ¡:', 1 : 1· ~} ,. " ,'.1,··· 1,1 ~ I :LL' I f i ,¡ f ,. - I' "I" 1· . I" .. .", " , 'I F. ~.' "j11···11 I .~.::1 f' f'¡¡:I.I.'·1:: ,,',1 ' ¡ 'tl . ·t' '¡'-'f" . I ., · , ¡ !:. ¡:' : d t I.· . ' . I . f 11"! 'I t 'Itlll'·" I·' .1"... ."......}, 'J, !~t':i.i: H¡H\Jiidl.·!.l' :.:" ~ ~d ',!!'L~11.J_1~H!f "I 1 : Cl 10 Na CJ HCO~ 1 Ca HC03 SO~ 1 Mg 804 f' C03 1 Fe ; . I! ' co. rli I ¡ ,: í I ' ()fa --. .. ~ u...- -..-... "a. ~ ... U) xon: 1f¡/1=K~ pc Sta K-va= xesç.. -.:~ pc H... ~ ~ ~=~ ~ . R~ -, '..-'__ tr..- ,,- - SCÞ~NNEO JUN 1 ~~11 20n~} #1 ARca Alaska, Inc. ~, Internal Corres(' 'ence Date: February 4, 1986 File code: ~~ ~~ Subject: Revised Draft - Kuparuk Area Injection Permit Application To/Location: Distribution ¡}- {tl -* :L ----------- From/Location: ~þ- Julie A. Athans, A TO-2034 Attached is a revised copy of the draft Kuparuk area injection permit application. This draft will be used for our discussions with the Alaska Oil and Gas Conservation Commission tomorrow, February 5, at 9:00 A.M. in ATO-2015. The purpose of the meeting is to review with the Commissioners the approach and level of detail in the draft permit application and the variances we are requesting. Distribution: John Bell, A TO-1406 Mark Drumm, ATO-1926 Dan Fortier, ATO-I026 Mike Hagood, A TO-ll28 George Phillips, A TO-1296 ~ JAA/jhl cc: A. J. Schuyler /J. M. Short, NSK C. Gar lasco, A TO-1962 ARca AI..ka. Inc, Is a Subsidiary of AtlantlcRlchfleldCompany AR3B-6001-A 8C/~NNEDI ~JUN 1 f?' 2004 { ( SECTION A Area Injection Order 20 AAC 25.460 ARCO Alaska, Inc., as operator of the Kuparuk River Unit, requests an area injection order be issued for current and proposed ¡njOctio~cpt.rations_ in-the UoH. ARCO requests ^ that the order allow ARCO to drill, operate, convert or plug and abandon wells within the Kuparuk River Unit by filing Form 10-401 or Form 10-403. Injection operations may bo r(\ tpgnr i 7Pd-as.---Waterflood.tenhanced---r-eeovery,- prodtte-ed-·,-w-a-t-er .... . disposa-l··---aftti--annu Ius i n.-jectinl")- The Oil and Gas Conservation Commission may, in its discretion, issue an area injection order if certain requirements are met. The Kuparuk River Unit injection operations meet the requirements of 20 AAC 25.460(a). Existing wells are described and identified by type. Injection wells are within the same field, are operated by a single operator and are used for other than hazardous waste injection. .. A ell"" ~"., r.tt t:øtl,Ii"' pf""Þ /.p~ f '~ full field waterfloQ~ was originally approved by Conservation Order No. 198, dated June 14, 1984, pursuant to 20 AAC.25.400. The startup of the Seawater Treatment Plant (STP) in October, 1985, initiated the full field waterflood, injecting treated Beaufort Sea water and produced water into the Kuparuk River Oil Pool. Oil recovery is expected to increase from an estimated 11 % OOIP from primary recovery alone to a primary plus secondary oil recovery of about 30% OOIP, or approximately 1.6 billion barrels of oil based on current reservoir interpretation. r-4r: NIIt·~s 1,1 al"4e4 ~ cI€,c, 1,;'" ot-tl"r; In addition to approval of fullfiolã wiltcrilood under tho current 3tQtuL\..~, the Kuparuk Owners make the following special requests as related to the previous rulings made in Conservation Order No. 198. 1. Waterflood Permit Area - the Waterflood Permit Area proposed herein differs from that previously approved in that it has been expanded, primarily to the north, to take in addi tionaÌ acreage that has been added to the Kuparuk Participating Area since June of 1984. The currently proposed Waterflood Permit Area is shown on the plat in Figure 8-1 and includes the governmental sections listed in Figure A-I. A-I ~CANNED JUN 1 7 2004 ( 2. Changes to the Waterflood Permit Area to allow it to expand with future changes to the Participating Area, as well as any other changes to the full field waterflood project that will enhance the efficiency of the project, should continue to be subject to approval by the Alaska Oil and Gas Conservation Commission by administrative action, as provided for in Rule 2 of the above named Order. 3. The provision made in Rule 1 of the abov~ named Order, allowing a well spacing of four wells per governmental quarter section should be extended to this and any other approved expansion of the Waterflood Permit Area. iIJo A-I 5Ct\N,~ED' JUN 1 t;¡ 20D4 @ ~I :;lP~ :;~~~~~ 1-£1 ~ ~J!f ~ ~ c5~ Øt. CðYI~Q>1 ~ ~-v-e..feþf::t ~ t:ë-/,fJ ~nJ~ ~::7~~ . /J /J . -LÞ U ~ ; Hill! cis ~ '"M.t-rfd{;eJ/ ~ /1ð'Yl- ñij¡ _ ðewJ k/Md.:r . ~ J;:'" wU ~ . ~ fA,. 17ft...! rf~ ø/ "'e:: t"" ~. ~~-s j~~ H~ :( ~-€fl4,J ~~ i d ð-I'"" ÁtU.I;, ~CR é. J~ (~~ . 1~c~ ~ ~ ?µ/ß-J< 71J¿ øL... fMj~e-f,~ ~.Pc-. Ù> /Utu.f.sf~/ .~o .R"'c.-.¡~ a#:¡~ úXd~ 6111 /~~¡ tf; y¥ ?H/k b(J_/ V4 ~ß7J '{ tß j;~nnf ¡(Jvu- Ph,~A dJtÀ ~t;S- 13yS- SCl\~\U'~E[I: \\;UN 1 ? 2004