7th ONE—DAY
`
`WELL TECHNOLOGY
`
`CONFERENCE ON
`
`HORIZONTAL
`
`“Horizontal Well Technology
`Operational Excellence”
`
`Wednesday, November 3, 1999
`Telus Convention Centre
`
`Calgary, Alberta, Canada
`
`PRESENTED BY:
`
`0 Canadian Section of the
`
`Society of Petroleum Engineers
`
`- The Petroleum Society of C/M -
`Horizontal Well Special Interest Group
`
`WEATHERFORD INTERNATIONAL, LLC, et al.
`
`EXHIBIT 1004
`
`WEATHERFORD INTERNATIONAL, LLC, et al.
`V
`
`PACKERS PLUS ENERG.Y SERVICES, INC.
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`
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`The Petroleum Society of ClM — Horizontal Well Special lnterest Group
`
`and
`
`The Canadian Section of the Society of Petroleum Engineers
`
`7th One Day Conference
`ALBERTA RESEARCH COUl\§ClL
`
`0“
`
`LlBRARY SEW/l:‘3§:IS DEF2*1;:‘iTlviENT
`
`250 iiaat
`Eomonroa, AL1"3EFiTA,
`raw‘ 3:54}
`
`HORIZONTAL WELL Technology
`
`Operational Excellence
`
`Wednesday, November 3, 1999
`
`Telus Convention Centre
`
`Calgary, Alberta, Canada
`
`Alberta Research Council Library
`
`
`
`
`ll
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`lll l l
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`llllllll
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` lll Ill
`0 1630 2010 030702 of 11
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`Production Control of Horizontal
`
`Wells in a Carbonate Reef
`
`Structure
`
`Bill Ellsworth — Husky Oil
`Marty Muir — Husky Oil
`John Gray — AI/ore Petroleum Management
`Dan Themig — Ha//iburton/Guiberson AVA
`
`THIS PAPER IS TO BE PRESENTED AT THE SEVENTH ONE DAY CONFERENCE ON HORIZONTAL WELL
`TECHNOLOGY, CALGARY, ALBERTA, CANADA, NOVEMBER 3, 1999.
`
`Abstract
`
`Introduction
`
`Open hole completions have been the accepted practice for
`horizontal wells in the Rainbow Lake area of Northern
`Alberta. As these fields mature, and the
`oil bank in these structures thin,
`the use
`
`75.? Rainbow Lake
`
`control
`production
`efiective
`of
`become particularly
`technology
`has
`important.
`The design of the well
`trajectory,
`the ability to intervene to
`control
`production,
`and
`the
`in
`incorporation
`of horizontals
`a
`strategic producing plan for the area has
`pushed the edge of technology. Many
`aspects of the planned exploitation of
`these reef pools have changed based
`upon successful applications of evolving
`horizontal
`well
`technologies.
`Production control issues are paramount
`to these changes.
`This paper presents
`several well case histories that illustrate
`
`in
`application of advancements
`the
`establishing isolation in the open hole
`horizontal completions
`to accomplish
`various objectives
`in
`the
`successful
`application of horizontal wells in the
`Rainbow Lake field.
`
`The Rainbow Lake area of northern Alberta contains several
`
`pools with carbonate reef structures. The formation tends to
`be a prolific producer due to high matrix
`permeability and porosity. Vertical wells have
`generally served as the primary producers and
`injectors. However, as drilling capabilities have
`improved, the use of directional, horizontal, and
`multi—leg well geometry’s have been utilized to
`both
`accelerate
`production,
`and
`improve
`ultimate recovery. While these wells have
`allowed
`improvements
`in
`the
`producing
`strategy of the field,
`it has also provided
`challenges, mainly
`concerning
`production
`methods
`and procedures.
`One of
`these
`challenges is providing long-term isolation in
`these mostly open hole horizontal completions.
`
`
`
`Figure 1 - The Rainbow Lake
`Field in Northern Alberta,
`Canada.
`
`Field Background
`
`Banff Oil and Gas discovered the first Keg
`River Pool of Rainbow Lake Field in the late
`
`series of ownership
`Through a
`l960’s.
`changes, this pool
`is now operated by Husky
`Oil.
`The field consists of several separate
`producing pools that are located in the Rainbow
`Lake area of Alberta. Some of the producing
`pools
`in
`the
`field
`contain
`vaulted
`
`I999 CIM Horizontal Well Conference
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`

`
`reef structures (see figure 2), each with variations in horizontal
`and vertical permeability as well as substantial reserves of oil
`and gas. The field was initially produced through primary
`production, mainly using gas lift. Both gas re-injection and
`water injection have been used as recovery mechanisms and to
`provide pressure maintenance for
`the field.
`Part of the
`Rainbow Lake Field is now under tertiary recover utilizing a
`solvent
`flooding procedure (See figure 3).
`This process
`requires that rich solvent gas be injected into the upper portion
`of the reservoir followed by chase gas. The chase gas moves
`through the structure pushing solvent through the rock, and
`sweeps incremental oil from the reservoir. During the process,
`the solvent front is moved either up or down using both water
`and gas injection to move the oil/water and the gas/oil contacts
`vertically through the reservoir.
`
`Rainbow Horizontal Program
`
`Although many parts of the reservoir are prolific, with high
`expected recovery, there are portions of the field that contain
`significant reserves, but are held in lower quality reservoir
`rock. Also, some of these areas may not be effectively drained
`during the primary production or the solvent flooding process.
`The objectives of some of the horizontal wells drilled to date
`have been to access these portions of the reservoir. Some of
`these segments could not be reached economically using
`vertical wells due to surface and facilities costs. Producing
`unswept oil is a primary application of these horizontal wells.
`Innovative designs of well geometry and configuration are
`required to reach these segments of the reserves.
`Improving the efficiency of the tertiary recovery is also a
`rim
`obective in the a
`lication of horizontal technolo
`.
`P
`313’
`J
`PP
`83’
`This application is somewhat more difficult due to the vertical
`mobilit
`and movement of the oil
`la er in the reservoir.
`Y
`Y
`Utilization of horizontal wells within the active solvent flood
`re uires timin as well as
`recise well
`lacement and se ment
`Cl
`8
`P
`P
`g
`isolation in the horizontal leg.
`
`
`
`\s\n\\wmmwmm\mm\~‘\1%W-
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`E
`E
`E ‘
`E 3.
`E .
`g
`E i
`E
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`%
`%
`
`
`
` }
`
`Challenges
`
`
`
`
`
`
`
`
`
`
`
`The application of horizontals creates several challenges. The
`primary challenge is to produce oil without excessive gas or
`water breakthrough (coning). While most of the horizontal
`wells lie in the lower segment of the reservoir,
`the build
`section of the well must pass through the upper gas cap,
`sometimes in two or more formations.
`Isolation of the gas has
`historically been accomplished using liners and cement. New
`drill horizontal wells are generally cased through these gas
`layers. However, an added challenge in re—entry horizontal
`wells is to isolate these zones without
`the benefit of the
`
`primary casing string. When possible, a 114mm (4-l/2”) liner
`is run and cemented through these gas intervals, and then the
`
`04 ofll
`
`Production control of horizontal wells in a carbonate reef structurl
`
`Figure 2 - Vertical injectors and producers have
`historically been used in the Rainbow Lake Field reef
`arch structures.
`
`remainder of the horizontal is drilled with 98.4mm (3-7/8”)
`slim hole MWD. This produces a smaller borehole, but is
`effective in isolating the gas while still allowing effective
`packer seats in the horizontal.
`
`Achieving Isolation
`
`With several hundred meters of open hole horizontal wellbore
`exposed, water or gas breakthrough can be a problem for some
`of these wells. Also, during drilling, the trajectory of a well
`may be low or high within the structure, causing a problem
`with premature coning of gas or water in the reservoir. The
`
`
`
`
`
`
`
`
`
`
`
`
`
`
`
`
`
`llflflllflll
`
`GAS ..
`
`l»
`
` mass’
`GA5«——'
`
`
`.
`sorvsm“
`
`'
`
`-
`
`V
`
`,,
`
`,
`
`.
`
`r:
`
`Figure 3 - Part of the field is under solvent flood,
`which is used to increase oil recovery.
`
`ability to establish long term isolation of segments within the
`
`
`
`04 of 11
`
`

`
`reservoir is key to controlling and optimizing production from
`these horizontal wells.
`
`Historically, inflatable packers were used for water shut—off,
`stimulation, and segment testing. More recently, solid body
`packers (SBP’s)
`(see Figure 4) have been used to establish
`open hole isolation. These tools provide a mechanical packing
`element that is hydraulically activated. The objective of using
`this type of tool is to provide a long~term solution to open hole
`isolation without the aid of cemented liners. Although the
`expansion ratios
`for
`these packers are as
`large as
`for
`inflatables, the carbonate formation in Rainbow Lake generally
`drills very close to gauge hole, and effective isolation is
`possible with these SBP’s. Effective isolation in open hole
`greatly increases the capability to incorporate horizontal wells
`into the producing strategy for the Rainbow Lake field.
`
`is
`seats)
`(packer
`isolation points
`Establishing effective
`approached both from a reservoir and a mechanical standpoint.
`First, the reservoir objectives are established.
`Issues such as
`seismic, log data, and drilling fluid losses and production are
`considered.
`Based upon this data, general areas of low
`porosity are selected to set packers in.
`The secondary
`consideration is the mechanical sealing of the SBP’s.
`If a
`caliper log is available, it is used to choose competent packer
`seats. The formations in Rainbow Lake often contain vugs and
`fractures. When possible,
`the packers are run in pairs to
`minimize the chance of failure due to setting in a vug. When
`caliper
`logs
`for
`the horizontal wells
`are not available,
`alternative data is used including drilling ROP’s and log data.
`
`Case Histories
`
`Case history #1 - Rainbow 14-12-110-8W6
`
`This well was drilled in 1993, and was cased to 90 degrees
`using 245mm (9-5/8”) casing. The producing leg was drilled
`using 216mm (8-1/2") bit from casing shoe to TD.
`Initially,
`the well produced clean oil. At the time of this workover, the
`well had excessive (unwanted) gas production. The objective
`of the workover was to isolate a segment of the well,
`to
`attempt reduce gas production. The well was to be segmented
`into three sections, with the ability to produce any or all of
`these sections.
`
`Welland Completion Design
`
`Two isolation points were selected and the SBP's were
`configured in pairs in order to improve the effectiveness of the
`isolation points. The tailpipe assembly consisted of a 73mm
`pump-out plug and no-go style profile nipple. The packers
`were supported with centralizers to aid in run-in. Between the
`
`Production Control of Horizontal Wells in a Carbonate Reef Structure
`
`sets of packers was a 73mm (2-7/8”) sliding sleeve. This
`allows for either producing or shutting off the center segment
`of the well. 73mm tubing was run throughout the lateral. The
`tubing was crossed over to 88.9mm (3-1/2”) inside the casing.
`An expansion joint was run to allow for testing of the open
`hole packers. A sliding sleeve was run in the vertical potion of
`the well. This provided an inflow point for the heel portion of
`the well.
`It also allows non-rig intervention (slickline) to
`control two of the three well segments. A cased hole double
`grip packer and on-off tool was run in the 244mm (9-5/8”)
`casing to anchor the assembly as well as to provide well
`control. (Figure 5)
`
`Installation and Operations
`
`The assembly was run into the well, and tubing pressure was
`applied to selectively set all of the open hole packers. Once
`they were set, tubing weight was applied to confirm the set.
`The cased hole packer was then set, and the on-off tool was
`used to circulate inhibited fluid into the annulus.
`
`Setting Cylinder
`
`Setting Shear
`
`Mandrel Lock
`
`Five Piece
`
`Packing
`Flnmnni
`
`Shear Release
`
`it
`
`Figure 4 - The solid body packer is
`hydraulic set instead of inflatable
`(Guiberson / Halliburton Wizard 11
`packer shown)
`
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`05 of 11
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`

`
`Production Control of Horizontal Wells in a Carbonate Reef Structure
`
`
`
`if
`
`is iE i lll 2ii
`
`ll
`i\
`.«
`
`l1
`
`ll. i1
`
`'il1. l6l\4
`
`. é
`
`ii.
`2-1 ‘
`
`Cased Hole Packer
`W/ On—Off Tool
`
`‘ <— Sliding Sleeve
`l
`.‘
`3
`
`Expansion
`Joint
`
`‘
`
`Open Hole Packers
`
`Sliding Sleeve /
`
`Figure 5 - The Solid Body Packers were used to segment the well, and provide isolation of the center portion of
`the well.
`
`Results
`
`This was the first installation of SBP’s for Husky in Rainbow
`Lake. Although the radial clearance between packer OD and
`
`E]Gas (E3m3/d)
`
`Water (m3/d)
`Oil (m3/d)
`
`After
`
`Figure 6 - Testing indicates change in production.
`
`drilled hole was small, the packers were successfully run and
`set. Some operational problems were encountered in the use of
`
`a mule—shoe re—entry guide that hung up near the casing shoe.
`This
`item was
`changed
`on
`subsequent
`installations.
`Production testing afterwards indicted that successful isolation
`was achieved as fluid ratios changed with changes in inflow
`sleeve selection (figure 6).
`
`The well initially had a high (uneconomic) GOR. After the
`workover, the well was produced only from a single interval
`(section 3).
`The GOR was initially lowered and water
`production increased. Eventually,
`the high GOR returned.
`Later, a sleeve was shifted to add section 2 to production. The
`GOR remained unchanged, but
`the water production was
`reduced.
`
`Case History #2 - Rainbow 13-32-109-8W6
`
`it.”
`
`from the
`Well #2 was designed to produce unswept oil
`reservoir structure.
`Based upon reservoir modeling, and
`seismic, it was determined that several "fingers" were present
`with recoverable reserves, that would not be swept with the
`existing recovery modes due to their location within the pool.
`This re-entry well included a 1 l4.3mm (4-l/2”) liner that was
`run and cemented through the build section to isolate
`unwanted productive intervals. The remainder of the well was
`drilled after the liner was set using a 98mm (3—7/8”) bit.
`
`
`
`ii
`
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`f
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`06 ofll
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`06 of 11
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`

`
`
`
`
`
`Isolation Packers
`
` _
`
`_
`Undrained Reservoir
`Segments \
`
`Cased Hole Packer
`
`‘
`
`Sliding Sleeve
`
`Sliding Sleeve
`
`Figure 7 - Horizontal well profile and isolation packers provide the ability to produce unswept oil within the field
`
`Production Control of Horizontal Wells in a Carbonate Reef Structure
`
`Well and Completion Design
`
`wireline.
`
`A horizontal well path was designed to pass through each of
`these unswept
`traps to allow existing injection and field
`pressurization to push production to these drainage points.
`Since the reservoir segments were not homogeneous,
`isolation
`points were selected to facilitate zonal shut—off and production
`optimization, should it be necessary (Figure 7).
`
`Installation and Operations
`
`Prior to running the production assembly, SBP’s were run to
`acidize the toe of the well. These were pulled, and the
`production assembly was run. The assembly was run into the
`well, and tubing pressure was applied to selectively set all of
`the open hole packers. Once they were set, tubing weight was
`applied to confirm the set. The cased hole packer was then set,
`and the on—off tool was used to circulate inhibited fluid into the
`
`completion design contained two isolation points
`The
`positioned between the reservoir segments. Each isolation
`point was established using two SBP’s separated by a full joint
`(IOM) of tubing.
`The tailpipe assembly
`consisted of a no-go profile nipple and a
`pump-out glass plug to allow pressurizing the
`tubing. The glass plug was utilized (instead
`of metal
`pump-out
`plug)
`to
`eliminate
`equipment debris (the expended plug) in the
`borehole, while allowing mechanical access
`to the toe of the well. The open hole packers
`were run on 60.3mm tubing and anchored to
`a mechanical
`cased hole packer.
`An
`expansion joint was used to allow for testing
`of the SBP’s before setting the cased hole
`packer.
`A sliding sleeve was
`installed
`between the isolation points to allow an
`inflow point for the middle well interval. A
`second sliding sleeve was run below the
`cased hole packer
`to provide access
`to
`production from the heel of the well. This
`sleeve was run in the vertical portion of the
`well
`so that
`it would be serviceable via
`
`
`
`<1
`3i
`
`li <
`
`5f ir
`
`1.t
`
`iI
`i.
`E(
`E<
`
`tY<E(
`
`Ti
`
`, ig
`
`t,
`
`2*
`E
`
`T
`
`
`
` Water (m3/d)
`E Oil (m3ld)
`
`El Gas (E3m3Id)
`
`
`
`8‘-roe
`
`Figure 8 - Wireline changes allow for isolation of separate producing
`intervals and production optimization.
`
`07 ofll
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`07 of 11
`
`

`
`Production Control of Horizontal Wells in a Carbonate Reef Structure
`
`
`
`Figure 9 - When a new lateral is added to an existing open hole horizontal well, solid body packers isolate and allow
`selective production of either lateral.
`
`annulus.
`
`Results
`
`the tools
`indicated that
`The initial acid job using SBP’s
`successfully provided isolation during the job. The acidizing
`assembly was pulled, and some rubber was left in the hole.
`
`This required a c1ean—out trip before running the production
`assembly. The production packer assembly was successfully
`run, and mechanical confirmation indicated that
`the SBP’s
`were holding.
`
`Production testing afterwards, as well as sleeve changes during
`the first 18 months indicted that successful
`isolation was
`
`D Gas (E3m3/d)
`
`Water (m3/d)
`
`I Oil (m3/d)
`
`Month 1
`
`
`
`oil/water/gas
`as
`achieved
`ratios during production have
`been changed
`significantly
`following changes in inflow
`selection
`points.
`The
`production
`has
`been
`alternated between producing
`the toe only and adding the
`heel. Changes were made in
`months 3, 8 and 16.
`The
`chart
`shown
`contains
`
`production results following
`downhole
`flow
`control
`
`changes. (Figure 8).
`
`
`
`3.
`
`t {
`
`i
`
`t E
`
`t if
`
`é‘
`E.4
`
`5 E2stE<
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`t.
`l<,E
`lI
`
`f
`
`.
`
`
`
`I l E
`
`Isolation Packers
`
`New Lateral
`xisting Lateral
`
`
` Open Hole
`
`Juncture
`
`Figure 10 - Isolation of the existing and the new leg provides the ability to select
`production from either or both laterals (rigless intervention).
`
`
`
`
`08 ofll
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`08 of 11
`
`

`
`Production Control of Horizontal Wells in a Carbonate Reef Structure
`
`Case History #3 Rainbow - 102/3-9-109-8 W6
`
`Well #3 was an existing horizontal well with a single leg. The
`purpose of the workover was to add a second producing leg.
`A hybrid service/drilling rig was used to sidetrack off the
`existing open hole leg, and to drill a directional well to access
`another portion of the reservoir.
`
`Well and Completion Design
`
`Well #3 has 178mm (7”) casing run to horizontal and
`cemented in place to isolate upper gas intervals. (Figure 9) A
`horizontal well path was designed to drill a sidetrack open hole
`leg to an undrained portion of the reservoir. After drilling the
`lateral, it was necessary to isolate the old leg from the new
`one,
`in order to produce either. The selected completion
`design established an isolation point just past the open hole
`lateral juncture. This was done using two SBP's separated by a
`full joint (l0M) of tubing. The tailpipe assembly consisted of
`a no—go profile nipple and a pump-out glass plug to allow
`pressurizing the tubing. The glass plug was utilized (instead of
`metal pump-out plug)
`to eliminate equipment debris (the
`
`expended plug) in the borehole, while allowing mechanical
`access to the toe of the well. The open hole packers were run
`on 73mm (2-7/8”) tubing and anchored to a mechanical cased
`hole packer. An expansion joint was used to allow for testing
`of the SBP's before setting the cased hole packer. A sliding
`sleeve was run below the cased hole packer to provide access
`to production from either lateral #1 or lateral #2 (the newly
`drilled lateral). This sleeve was run in the vertical portion of
`the well so that it would be serviceable via wireline.
`
`Installation and Operations
`
`Prior to running the production assembly, a clean—out trip was
`made with a bit and tubing (no directional equipment). The
`objective was to install the packer assembly in the new lateral.
`When the assembly was run.
`it entered the old lateral by
`mistake. The assembly was pulled and a second clean-out trip
`was made. The packer assembly was then re-run and entered
`the second leg as planned. Tubing pressure was applied to
`selectively set all of the open hole packers. Once they were
`set, tubing weight was applied to confirm the set. The cased
`hole packer was then set, and the on—off tool was used to
`
`‘— Cased Hole Packer
`
`
`
`1--it 4—— Sliding Sleeve
`)3
`
`
`
`
`Isolation Packers
`
`‘
`
`Sulphur Point Gas
`
`Zone Segregation
`
`/
`
`'/m ///',
`/
`/V//'/..'
`
`
`
`5.,._..A..*(-...R...“rV\/r~1l~I4-.a\.«.,..¢-,4...._\M»a
`
`
`
`
`
`
`//// /
`
`/
`
`Sliding Sleeves
`
`Figure 11 - Lining the build section for re-entry horizontal wells using tubing and solid body isolation packers has proven
`feasible to isolate upper gas sands.
`
`09 ofll
`
`
`09 of 11
`
`

`
`circulate inhibited fluid into the annulus. The glass plug was
`expended, and the well produced from the toe of the leg #2.
`Results
`
`Some problems were encountered while attempting to get into
`the correct lateral. However, the production packer assembly
`was successfully run, and mechanical confirmation indicated
`that the SBP’s were holding.
`
`Production testing afterwards, as well as sleeve changes during
`the first 6 months indicated that successful
`isolation was
`
`achieved as oil/water/gas ratios during production have been
`changed significantly following changes in inflow selection to
`the different laterals.
`In particular, the gas production changed
`significantly during this process. The chart shown contains
`production results following downhole flow control changes
`(figure 10).
`
`Case History #4 - Rainbow 16-20-110-7 W6
`
`Well #4 was a re-entry horizontal well from 139mm (5-1/2”)
`casing. The sidetrack was done from an existing well, and the
`build section of this well drilled through unwanted productive
`intervals. Two horizontal legs were drilled into the producing
`formation. The completion assembly was designed to isolate
`between these legs and within the build section of the well.
`It
`also required testing of the interval
`in the build section to
`verify isolation.
`
`Well and Completion Design
`
`This well was originally a vertical producer. A sidetrack
`window was cut
`in the 139mm casing, and both the build
`section and horizontal legs were drilled using a l20.6mm (4-
`3/4") bit. The target producing segment of the well had a
`second open hole lateral drilled using an open hole sidetrack.
`A single isolation point was selected in the primary producing
`leg (leg #2) to allow selective production from either or both
`legs. This was done using two SBP's separated by a full joint
`(l0M) of tubing placed in the primary producing leg (Figure
`11).
`
`The build section of the well was segmented into two separate
`intervals using two SBP's. These were separately spaced using
`tubing joints and pups and included sliding sleeves to permit
`flow tests to confirm isolation within the build section. The
`
`tailpipe assembly consisted of a no—go profile nipple and a
`pump—out glass plug to allow pressurizing the tubing, while
`allowing mechanical access to the toe of leg #2. The open
`hole packers were run on 73mm tubing and anchored to a
`mechanical cased hole packer. A downhole tubing swivel was
`installed just below the cased hole packer to facilitate setting
`and releasing.
`
`Production Control 0fH0riz0ntal Wells in a Carbonate ReefStructure
`
`Installation and Operations
`
`Prior to running the production assembly, a clean—out trip was
`made with a bit, reamer and drill pipe. The packers were
`spaced using tubing to place them at the appropriate isolation
`points, with the spacing of the build section packers being
`particularly crucial. The assembly was run and logged on
`depth. The mechanical cased hole packer was set to place the
`SBP's at the chosen isolation points. The cased hole packer
`was then pressure tested (annulus
`test)
`to insure casing
`integrity. After the casing packer was set, tubing pressure was
`applied to selectively set all of the open hole packers and the
`glass plug was left in place to plug the toe during production
`testing, then later expended to open the toe.
`
`
`
`To confirm that the packers were providing zonal isolation, a
`series of production flow tests were performed. The flow tests
`were conducted using wireline plugs and shifting tools to
`provide rigless intervention.
`
`Results
`
`The top sliding sleeve was opened, and the Sulfur Point was
`tested. Gas and water
`inflow was recorded, with pressure to
`flow to surface. The sleeve was closed; sliding sleeve #2 was
`opened, and the Muskeg was tested. Pressure bled off, and the
`formation was swabbed dry to indicate isolation. Sleeve #2
`was closed, and the tubing was pressured to blow out (expend)
`the glass pump—out plug. Lateral #2 was produced with oil
`cuts of 35-50%. The leg was then acidized through the tubing
`string, and swabbed back. Slickline was rigged up, and the
`sliding sleeve for leg #1 was opened, with this production
`added to leg #2. The ‘well was put on production. Long term
`production results were not available at the time this paper was
`written, but the primary objective of zonal segmentation in the
`build section of this well was clearly demonstrated (figure 12).
`
`Summary
`
`The ability to establish long—term zonal isolation in open hole
`producers opens the door
`to many new well producing
`configurations. The goal of cost effective use of horizontals
`can be enhanced with the ability to segment, and control
`production without the need to run and cement liners.
`It is
`also possible to change producing configurations by working
`over the well, and changing the production intervals as some
`future date.
`
`Another key to the completion design is to configure the
`installation to minimize well
`intervention costs.
`In the
`
`Rainbow Lake area, coiled tubing costs are quite expensive.
`Where possible, the flow control devices were moved to the
`near vertical portion of the well
`to allow for
`slick—line
`changing of
`inflow devices
`(sliding sleeves or ported
`mandrels). This strategy has proven very effective when it is
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`Production Control ofHoriz0ntal Wells in a Carbonate ReefStructure
`
`operationally feasible. Other considerations such as sour
`service
`equipment
`requirements,
`scale
`and
`asphaltines
`deposition, and corrosion have been addressed in job designs.
`
`experience as a drilling engineer include both domestic and
`international operations. land and offshore projects. Bill is a
`member of APEGGA, SPE and CADE.
`
`a Petroleum Engineering Consultant with
`John Grey is
`extensive drilling and completion experience. He has a B.Sc.
`degree in Mechanical Engineering from the University of
`Saskatchewan and is a Registered Professional Engineer as
`well as a member of SPE.
`
`for Guiberson AVA /
`Dan Themig is Account Leader
`Halliburton Energy Services. He has served in various job
`responsibilities in Canada and the U.S. including team leader
`for Multilateral Development Projects for Dresser Oil Tools in
`Dallas, Texas. He received a BS in Engineering from the
`University of Illinois and an MBA from Oklahoma State
`University. He is a Registered Professional Engineer,
`is a
`member of SPE, and has authored various articles and SPE
`papers on completion related subjects.
`
`These case histories illustrate examples some of the various
`production control applications in horizontal wells using
`SBP’s.
`These types of completion capabilities are now
`considered during the well planning stages. As capabilities
`have beep successfully verified,
`the
`aggressive use of
`horizontal drilling technology in conjunction with innovative
`completion and depletion strategies have enhanced the ability
`to produce the Rainbow Lake Field.
`
`Conclusions
`
`0
`
`0
`
`0
`
`The horizontal well design is often predicated on
`completion capabilities
`
`SBP’s have successfully provided zonal isolation
`
`The potential use of horizontal wells has been enhanced
`
`0 When designing a producing installation, minimizing
`intervention costs is an important consideration
`
`0
`
`Candidate selection is important
`
`Acknowledgments
`
`The authors of this paper wish to thank the management of
`Husky Oil, Mobil Oil and Halliburton Energy Service for the
`permission to present and publish this paper.
`
`Authors
`
`Marty Muir is a Completion’s Staff Engineer with Husky Oil
`Operations Ltd. He is a Professional Engineer, and a member
`of both SPE and the Petroleum Society of CIM.
`Prior to
`joining Husky Oil he held positions
`in production and
`reservoir engineering with a senior Canadian Oil and Gas
`Exploration and Production Company. Previous to that as a
`field engineer with an international wireline company. He has
`a B.Sc. degree in Mechanical Engineering from the University
`of Calgary
`
`Bill Ellsworth, P.Eng., is Engineering Manager, Drilling and
`Completions for Husky Oil Operations Ltd. He has a Bachelor
`of Chemical Engineering from Nova Scotia Technical College,
`Halifax (TUNS/DALTECH) and an Engineering Diploma
`from St Francis Xavier University (STFXU Antigonish). Work
`
`
`
`
`
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